PJM Identified Issues and Planned Solutions Near the MISO Seam Annual Issues Review - www.pjm.com
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PJM Identified Issues and Planned Solutions
Near the MISO Seam
Annual Issues Review
www.pjm.com PJM©2017
Notes
• This slide deck provides a summary of significant transmission projects
near the PJM – MISO seam which have been added or modified in 2017
• It is not a comprehensive review of all planned projects
• Where projects were presented on multiple occasions, efforts were made
to only include the latest information here
• For additional information:
• TEAC: http://pjm.com/committees-and-groups/committees/teac.aspx
• Subregional RTEP Committee – Western: http://pjm.com/committees-
and-groups/committees/srrtep-w.aspx
PJM TEAC – 8/10/2017 2 PJM©2017
Links for Various Information related to PJM Planning
• Transmission Expansion Advisory Committee (TEAC)/PJM RTEP Windows
• http://www.pjm.com/committees-and-groups/committees/teac.aspx
• Interregional Planning
• http://www.pjm.com/planning/interregional-planning.aspx
• Queue (future) Generation
• http://pjm.com/planning/generation-interconnection.aspx
• Generation Deactivation
• http://www.pjm.com/planning/generation-deactivation.aspx
• Proposal Windows
• http://www.pjm.com/planning/rtep-development/expansion-plan-process/ferc-order-1000/rtep-
proposal-windows.aspx
3 PJM©2017
System Expansion Drivers for RTEP 4 PJM©2017
Identified Issues: Reliability
All in One Window for 2022
www.pjm.com PJM©2017
Analysis of 2022 - Violations
• 190 flowgates
• 2022 conditions
• Summer, Winter &
Light Load
• Includes both
voltage and
thermal violations
PJM TEAC – 8/10/2017 6 PJM©2017
2022 Analysis Violations
Count of Load N-1 Load N-1 N-1 Voltage N-1-1 Voltage Grand
FG # Gen Deliv Deliv Drop Thermal High Thermal High Total 80
69 3 1 4
MAAC 3 1 4 70
South 0
115 8 2 10 60
MAAC 7 2 9
South 1 1 50 Voltage High
138 51 2 2 14 8 77
N-1-1 Thermal
MAAC 1 2 2 5 N-1 Voltage High
40
West 50 2 14 6 72 N-1 Thermal
161 14 3 2 19 N-1 Load Drop
30
West 14 3 2 19 Load Deliv
230 33 1 34 Gen Deliv
MAAC 27 1 28 20
South 6 6
345 6 5 35 46 10
MAAC 5 35 40
West 6 6 0
Grand MAAC MAAC South MAAC West West MAAC South MAAC West
Total 115 3 2 17 5 11 37 190 69 115 138 161 230 345
PJM TEAC – 8/10/2017 7 PJM©2017
2017 RTEP Proposal Window 1 - Overview
Overview of 2022 Results
Total of 190 flowgates identified
– 40 included in the window
• 32 in West region
• 5 in the South region
• 3 in the MAAC region
– 150 flowgates excluded
• Immediate need (PJM OA 1.5.8(m)) (Includes Generator Deactivation related)
• < 200kV (PJM OA 1.5.8(n))
PJM TEAC – 9/14/2017 8 PJM©2017
2017 RTEP Proposal Window 1 - Violations
• 40 flowgates are
window eligible
• Includes both
voltage and
thermal violations
PJM TEAC – 9/14/2017 9 PJM©2017
2017 RTEP Proposal Window 1 - Statistics
• Timeline
– Window Opened: July 11th, 2017
– Window Closed: August 25th, 2017
• Proposal definitions, simulation data and detailed cost data all due
at this time
• PJM requested proposals for 40 reliability violation flowgates
• 51 Proposals received from 10 entities addressing 9 target zones
– 29 Greenfield
– 22 Transmission Owner Upgrade
PJM TEAC – 9/14/2017 10 PJM©2017Identified Issues: Market Efficiency www.pjm.com PJM©2017
Identified Issues: Market Efficiency • PJM’s market efficiency process runs on a two year cycle • Issues were identified in October of 2016, and included in last year’s annual issues review PJM TEAC – 9/14/2017 12 PJM©2017
2016-2017 24-Month Market Efficiency Cycle
• Long term proposal window: Nov 2016 - Feb 2017
• Mid-cycle update of major assumptions: Jan 2017 – Apr 2017
• Load forecast, Fuel prices, Generation expansion, Network topology
• Only updating the most significant changes, not full update.
• Analysis of proposed solutions: May 2017 - Oct 2017
• Independent consultant review of cost and ability to build
• Review of analysis with TEAC: Jun 2017 - Nov 2017
• Determination of final projects: Dec 2017
• Final review with TEAC and Board approval
• Projects may be approved earlier if analysis and review complete
PJM TEAC 03/09/2017 13 PJM©20172016-2017 Long Term Window – Projects Received
• 96 market Efficiency Proposals
• 52 Greenfield
• $15.8M - $371.3M
• 44 Upgrades
• $0 - $192.07M
• 20 proposing entities (including 6 combinations of joint proposals)
• 8 Interregional proposals
• 5 Greenfield
• 3 Upgrades
PJM TEAC 03/09/2017 14 PJM©20172016-2017 Long Term Window Proposals PJM TEAC 04/13/2017 15 PJM©2017
2016-2017 Long Term Proposal Window 1A
• Addendum to the 2016-2017 Long Term Proposal Window closed on Feb 2018
– Will be designated as 2016-2017 Long Term Proposal Window 1A.
– Opening on September 14, 2017
– Closing on September 28, 2017.
– Solicit proposals to address the Tanners Creek - Dearborn 345 kV thermal constraint,
which is a Reliability Pricing Model (RPM) constraint.
• Target facility Tanners Creek - Dearborn 345 kV is the next limiting element in
the 2020/2021 RPM Base Residual Auction CETL study for the DEOK LDA*
.
• All participants of the 2016-2017 Long Term Proposal Window remain eligible
to participate.
* After RTEP baseline upgrade b2831 (Upgrade the Tanner Creek - Miami Fort 345 kV circuit) is constructed
16 PJM©2017
PJM TEAC – 9/14/2017Planned Upgrades: Baseline Reliability www.pjm.com PJM©2017
ATSI Transmission Zone
• Project Scope Change - B2557
• Targeted Violation: The Avon 345/138 kV transformer #92 is
overloaded for line fault stuck breaker contingency loss of Avon –
Juniper 345 kV circuit and Avon 345/138 kV transformer #91
• Original Scope: At Avon 345 kV substation, replace the existing
345/138 kV 448 MVA #92 transformer with a 560 MVA unit
• Original Cost: $5.4M (Updated cost: $6.0M)
• Required IS date: 6/1/2019
• New Scope: Re-configure the existing Avon 345kV substation into a
breaker-and-a-half layout
• New Cost: $5.7M
• Reasons:
– The new configuration eliminates the contingency (stuck
breaker) causing the identified thermal overload.
– Eliminates the 345kV source, bus, and transformer loss at
Avon for the stuck breaker contingency.
– New layout provides increased operational flexibility including
transformer and breaker maintenance.
– Significant decrease in post contingency loading for the Avon
transformers as a result of the new configuration when
compared to the transformer replacement project.
– Provides reliability improvement for the broader BES Network
by eliminating the thermal violation.
– After additional engineering design and cost reviews, the cost
for the 345kV breaker configuration project is the least cost
planning alternative.
PJM TEAC - 2/9/2017 18 PJM©2017ATSI Transmission Zone
• 2016 RTEP Proposal Window #3
• Common Mode Outage Violations (FG#
1, 2, and 3):
• Richland to Naomi Junction 138 kV circuit
is overloaded for multiple bus and line
fault stuck breaker contingencies.
• Continued on the next slide…
PJM TEAC – 5/4/2017 19 PJM©20172016 RTEP Proposal Window 3
ATSI Transmission Zone
Previously Presented: 5/4/2017, 4/13/2017
Recommended Solution:
PJM Proposed Solution: Transmission
Owner Upgrade to Relocate the Richland to
Ridgeville 138KV line from Richland J bus to
K, extend the K bus and install a new
breaker. (B2875)
Designated Entity: FirstEnergy (ATSI)
Estimated Project Cost: $1.7M
Required IS Date: 6/1/2019
Cancel B2558: Close normally open switch
A 13404 to create a Richland J Bus -
Richland K Bus 138 kV line. Estimated Cost:
$0.02M
Required IS Date: 6/1/2019
PJM TEAC – 6/8/2017 20 PJM©2017AEP Transmission Zone Previously Presented: 5/4/2017 Problem • Stuart and Killen deactivations • Generation Deliverability Outage: Jefferson – Clifty Creek 345 kV line is overloaded for the stuck breaker contingency tripping the Greentown – Jefferson 765 kV line and the Hanging Rock – Jefferson 765 kV line Immediate Need: Due to the immediate need, the timing required for an RTEP proposal window is infeasible. As a result, the local Transmission Owner will be the Designated Entity. Recommended: • Increase rating of the Jefferson – Clifty Creek 345 kV line (b2878) Estimated Project Cost Change: $0.1 M Required IS Date: June 1, 2018 Projected IS Date: June 1, 2019 www.pjm.com 21 PJM©2017
OVEC Transmission Zone
Baseline Project
Baseline Reliability – Generator Deliverability and
Common Mode Violation (pending OVEC integration into
PJM)
Problem Statement: The Dearborn – Clifty 345KV line is
overloaded for the loss of either the JK Smith – Dale 138kV
line or the Jefferson – Greentown 765kV line fault with a stuck
breaker at the Jefferson 765kV.
Immediate Need Solution:
Due to the immediate need, the timing required for an RTEP
proposal window is infeasible. As a result, the local
Transmission Owner will be the Designated Entity.
Recommended Solution:
Perform a LIDAR study on the Clifty Creek - Dearborn 345 kV
line to increase the Summer Emergency rating above
1023MVA). (B2943)
Estimated Project Cost: $0.168 M
Required IS Date: 6/1/2018
PJM TEAC – 9/14/2017 22 PJM©2017ATSI Transmission Zone
Baseline Project
Baseline Reliability – Operational Performance
High Voltage at Davis Besse
Problem Statement:
Over the past year, Transmission Operations and the Davis Besse nuclear
power plant have experienced high voltage operational alerts and warnings
due to transmission system voltages that have exceeded the power plants
technical specification limits under system light load conditions.
Immediate Need:
Due to the immediate need, the timing required for an RTEP proposal
window is infeasible. As a result, the local Transmission Owner (TO) will be
the Designated Entity.
Recommended Solution:
Install a 100MVAR 345kV shunt reactor at Hayes substation (B2942.1)
Install a 200MVAR 345kV shunt reactor at Bayshore substation (B2942.2)
NOTE: An existing operational switching solution has been implemented in
the past to assist with in the mitigation of the high system voltage until a
solution is fully implemented.
Continued on next slide…
PJM TEAC – 09/14/2017 23 PJM©2017ATSI Transmission Zone
Baseline Project
Baseline Reliability – Operational Performance
High Voltage at Davis Besse
…Continued from previous slide
Estimated Project Costs:
Hayes substation reactor (B2942.1) - $5.7M
Bayshore substation reactor (B2942.2) - $5.0M
Required IS Date: Now
Projected IS Date:
10/31/2017 for Hayes substation reactor (B2942.1)
10/31/2018 for Bayshore substation reactor (B2942.2)
Benefit:
Operational flexibility to adjust the system voltage at the Davis Besse
345kV bus under light conditions with both reactors on-line.
PJM TEAC – 09/14/2017 24 PJM©2017AEP Transmission Zone AEP Transmission Owner Criteria Violation Presented: 5/31/2017 Western Subregional TEAC Problem Statement: Low voltage violation (0.905 pu) at West Hicksville station for loss of the South Hicksville 69 kV bus in the 2021 RTEP case. –Hicksville, Ohio Recommended Solution: Install a 14.4 MVAr capacitor bank at West Hicksville station. Replace ground switch/MOAB at West Hicksville with a circuit switcher (B2798) Estimated Project Cost: $1.3 M Required In Service Date: 6/1/2021 www.pjm.com 25 PJM©2017
AEP Transmission Zone AEP Transmission Owner Criteria Violation Presented: 5/31/2017 Western Subregional TEAC Problem Statement: Numerous thermal and voltage deviation violations on the Kingsport 34.5 kV sub-transmission system for various N-1 and N-1-1 outages were identified in the 2021 RTEP case.–Kingsport, TN Recommended Solution: Install a second transformer at Nagel station, comprised of 3 single phase 250MVA 500/138kV transformers. Presently, TVA operates their end of the Boone Dam – Holston 138 kV interconnection as normally open preemptively for the loss of the existing Nagel 500/138 kV XF. By adding a second 500/138 kV transformer at Nagel, TVA will close in the interconnection, providing an additional source to the Kingsport area. (B2884) Estimated Project Cost: $13M Required In Service Date: 6/1/2021 www.pjm.com 26 PJM©2017
AEP Transmission Zone AEP Transmission Owner Criteria Violation Presented: 5/31/2017 Western Subregional TEAC Problem Statement: N-1-1 analysis identified an overload of the East End Fostoria-West End Fostoria 69 kV line and low voltage violations on the 69 kV system for loss of the West End Fostoria 138/69 kV transformer and the Buckley Road 138/69 kV transformer in the 2021 RTEP case. At West End Fostoria, 69 kV circuit breakers S and BB are vintage GE, FK and Allis-Chalmer, FZO model oil filled circuit breakers manufactured in 1965 and 1961. Furthermore, the maintenance has become difficult due to the oil handling required to maintain them. Oil spills are frequent with breaker failures and routine maintenance and can become an environmental hazard. The West End Fostoria breakers have the following documented conditions: unavailability of spare parts, obsolete interrupting medium, PCB content, and age. The installation of a high side CB to replace the existing transformer #5 MOAB “XX” will eliminate the need to isolate the entire 138 kV bus for a transformer fault. This will ensure the path to Melmore/Chatfield, Lemoyne(FE) and Fostoria Central will remain intact for loss of the existing transformer. –Fostoria, OH Recommended Solution: Install 90 MVA 138/69 kV transformer, new transformer high and low side 3000 A 40 kA CBs, and a 138 kV 40 kA bus tie breaker at West End Fostoria. (B2886) Estimated Project Cost: $3.2M Required In Service Date: 6/1/2021 www.pjm.com 27 PJM©2017
AEP Transmission Zone Common Mode Violation Presented: 9/11/2017 Western Subregional TEAC Problem Statement: Clinchfield – Fletcher Ridge 138kV line is overloaded for the loss of Broadford – Saltville 138kV line with the stuck breaker at Saltville 138kV (GD-S862) Recommended Solutions: Replace the existing 636 ACSR 138 kV Bus at Fletchers Ridge with a larger 954 ACSR conductor (B2937) Estimated Project Cost: $0.63M Required In Service Date: 6/1/2022 www.pjm.com 28 PJM©2017
DEOK Transmission Zone Short Circuit Violation Presented: 6/30/2017 Western Subregional TEAC Problem Statement: The Todhunter 138 kV breakers ‘931’, ‘919’, and ‘913’ are overstressed for a fault at Todhunter 138 kV. Recommended Solution: Replace Todhunter 138 kV breakers ‘931’, ‘919’, and ‘913’ with 80 kA breakers (B2894) Estimated Project Cost: $1.967 M (total) Required In Service Date: 6/1/2021 www.pjm.com 29 PJM©2017
DEOK Transmission Zone Short Circuit Violation Presented: 6/30/2017 Western Subregional TEAC Problem Statement: The Dicks Creek 138kV breaker “963” is overstressed Immediate Need: Due to the immediate need, the timing required for an RTEP proposal window is infeasible. As a result, the local Transmission Owner will be the Designated Entity. Recommended Solution: Replace the Dicks Creek 138kV breaker “963” with 63kA breaker (B2895) Estimated Project Cost: $300 K Required In Service Date: 6/1/2019 www.pjm.com 30 PJM©2017
ComEd Transmission Zone >300 MW Load Loss Presented: 9/11/2017 Western Subregional TEAC Problem Statement: >300MW load loss for the loss of the 138kV tower lines L4605 (Des Plaines – Busse – Schaumburg – Landmeier – Tonne 138kV “Red” line) and L4606 (Des Plaines – Busse – Schaumburg – Landmeier –Tonne 138kV “Blue” line) (N1-SLD1) Immediate Need: Due to the immediate need, the timing required for an RTEP proposal window is infeasible. As a result, the local Transmission Owner will be the Designated Entity. Recommended Solution: Build an indoor new Elk Grove 138kV GIS substation at the point where Rolling Meadows & Schaumburg tap off from the main lines, between Landmeier and Busse. The four 345 kV circuits in the ROW will be diverted into Gas Insulated Bus (GIB) and go through the basement of the building to provide clearance for the above ground portion of the building. (B2941) Estimated Project Cost: $90M Projected In Service Date: 6/1/2021 www.pjm.com 31 PJM©2017
EKPC Transmission Zone EKPC Transmission Owner Criteria Violation Presented: 5/31/2017 Western Subregional TEAC Problem Statement: Low voltage at Williamstown 69kV bus for the loss of the Munk Jct.- Williamstown 69kV line and JK Smith Unit 9. Recommended Solution: Increase Williamstown cap bank to 11.225 MVAR (B2786) Estimated Cost: $0.02M Required In Service Date: 12/1/2021 www.pjm.com 32 PJM©2017
EKPC Transmission Zone EKPC Transmission Owner Criteria Violation Presented: 5/31/2017 Western Subregional TEAC Problem Statement: Low voltage at the Deatsville distribution substation during the loss of the Bullitt County-Deatsville Tap 69 KV line section. Thermal overload of the South Bardstown – West Bardstown Jct. 69kV line during the loss of the Bullitt County 138/69 KV transformer. Other Considerations: EKPC Reliability Team identified concerns related to the age and condition of this conductor during their conductor assessment. The Reliability Team identified this entire line section as one of the top line sections to be addressed based on condition of the conductor and age of the line. Recommended Solution: Re-build the existing (1.5 mile), 1/0 MCM ACSR South Bardstown – West Bardstown Jct. 69kV line using 556.5 MCM ACTW conductor. (B2893) Estimated Cost: $1.03M Required In Service Date: 6/1/2017 www.pjm.com 33 PJM©2017
EKPC Transmission Zone EKPC Transmission Owner Criteria Violation Presented: 6/30/2017 Western Subregional TEAC Problem Statement: Low voltage at the Upchurch 69 kV station during the loss of the Zula Jct. – Upchurch Tap 69 kV line section. Recommended Solution: Resize the Albany 69 KV capacitor bank from 8.4 to 13.776 MVAR. (B2905) Estimated Project Cost: $0.09M Required In Service Date: 6/1/2026 www.pjm.com 34 PJM©2017
EKPC Transmission Zone EKPC Transmission Owner Criteria Violation Presented: 6/30/2017 Western Subregional TEAC Problem Statement: Overload of Clay Village - KU Clay Village 69 kV Tap during an outage of the KU Ghent – Owen Co- Scott Co 138 kV line section. Recommended Solution: Upgrade the metering CT associated with the Clay Village - KU Clay Village 69 kV Tap line section to 600 A; at least 64 MVA Winter LTE; Upgrade the distance relay associated with the Clay Village - KU Clay Village 69 kV Tap line section to at least 64 MVA Winter LTE. (B2907) Estimated Project Cost: $0.125M Required In Service Date: 12/1/2024 www.pjm.com 35 PJM©2017
EKPC Transmission Zone EKPC Transmission Owner Criteria Violation Presented: 6/30/2017 Western Subregional TEAC Problem Statement: Overload of Elizabethtown #2 - Tharp 69 kV Tap line section during the loss of KU Rogersville - Rogersville Junction 69 kV line. Recommended Solution: Increase the MOT of the EKPC Elizabethtown - Tharp Tap 69 kV line section (1.7 miles) to 302°F. (LTE at 284°F) (B2909) Estimated Project Cost: $0.2M Required In Service Date: 12/1/2026 www.pjm.com 36 PJM©2017
EKPC Transmission Zone EKPC Transmission Owner Criteria Violation Presented: 6/30/2017 Western Subregional TEAC Problem Statement: Overload of the Glendale - Hodgenville 69 kV line section during the loss of KU Elizabethtown - KU Elizabethtown #4 69 kV line section. Recommended Solution: Upgrade the distance relay at the Hodgenville station associated with the Glendale - Hodgenville 69 kV line section to at least 90 MVA Winter LTE. (B2910) Estimated Project Cost: $0 Required In Service Date: 12/1/2026 www.pjm.com 37 PJM©2017
EKPC Transmission Zone EKPC Transmission Owner Criteria Violation Presented: 6/30/2017 Western Subregional TEAC Problem Statement: Overload of the KU Russell Springs- Russell Co 69 kV line section during the loss of the Summer Shade - West Columbia 69 kV line. Recommended Solution: Upgrade the existing S408-605, 600 A KU Russell Springs Tap - Russell County 69 kV disconnect switch to 1200 A. (B2912) Estimated Project Cost: $0.15M Required In Service Date: 12/1/2025 www.pjm.com 38 PJM©2017
EKPC Transmission Zone EKPC Transmission Owner Criteria Violation Presented: 6/30/2017 Western Subregional TEAC Problem Statement: Overload of the Stephensburg-Glendale 69 kV line section during an outage of the KU Elizabethtown - KU Elizabethtown #4 69 kV line section. Recommended Solution: Upgrade distance relay at the Stephensburg station associated with Stephensburg - Glendale 69kV line section to at least winter LTE 100 MVA. (B2913) Estimated Project Cost: $0 Required In Service Date: 12/1/2024 www.pjm.com 39 PJM©2017
EKPC Transmission Zone EKPC Transmission Owner Criteria Violation Presented: 6/30/2017 Western Subregional TEAC Problem Statement: Overload of the Tharp Tap - KU Elizabethtown 69 kV line section during the loss of the Rogersville – Rogersville Jct. 69 kV line section. Recommended Solution: Rebuild Tharp Tap-KU Elizabethtown 69kV line section to 795 MCM (2.11 miles). (B2914) Estimated Project Cost: $1.22M Required In Service Date: 12/1/2024 www.pjm.com 40 PJM©2017
EKPC Transmission Zone EKPC Transmission Owner Criteria Violation Presented: 6/30/2017 Western Subregional TEAC Problem Statement: Low voltage at the Powell Taylor 69 kV station during the loss of the KU Florida Tile Tap-Lawrenceburg 69kV line section. Recommended Solution: Install a 69 kV, 15.31 MVAR capacitor bank at South Anderson substation. (B2919) Estimated Project Cost: $0.365M Required In Service Date: 12/1/2026 www.pjm.com 41 PJM©2017
EKPC Transmission Zone EKPC Transmission Owner Criteria Violation Presented: 6/30/2017 Western Subregional TEAC Problem Statement: Low voltage on the EK Bromley 69 kV bus during the loss of the Owen County Jct 1 – EK Bromley 69 kV line section. Recommended Solution:Rebuild Boone - Big Bone Tap 69 kV line section using 556.5 MCM ACTW conductor (6.3 miles). (B2920) Estimated Project Cost: $3.625M Required In Service Date: 12/1/2025 www.pjm.com 42 PJM©2017
EKPC Transmission Zone www.pjm.com 43 PJM©2017
EKPC Transmission Zone
EKPC Transmission Owner Criteria Violation
Presented: 7/21/2017 Western Subregional TEAC
Recommended Solution:
• New TVA 161kV Interconnection to TVA's East Glasgow Tap-East Glasgow 161 KV line section (~1 mile due West of Fox Hollow).
Add Fox Hollow 161/69 KV 150 MVA transformer. Construct new Fox Hollow-Fox Hollow Jct 161 KV line section using 795 MCM
ACSR (~1 mile) and new 161kV switching station at point of interconnection with TVA. (B2921)
• Cancel B2414 and B2710
Estimated Cost: $18.1M
Required In Service Data: 6/1/2018
www.pjm.com 44 PJM©2017EKPC Transmission Zone Winter Generator Deliverability Violation Presented: 9/11/2017 Western Subregional TEAC Problem Statement: The Wayne Co – Wayne Co KY 161kV line is overloaded for the loss of the Summer Shade 161kV bus section S11-1039. (GD-W314, GD-W483) Recommended Solutions: Upgrade the distance relay on the Wayne Co – Wayne Co KY 161kV line to increase the line winter rating would be 167/167. (B2940) Estimated Project Cost: $0M Required In Service Date: 6/1/2022 www.pjm.com 45 PJM©2017
ATSI Transmission Zone
• Project Scope Change - B2557
• Previously Presented: 9/25/2014, 2/9/2017
• Targeted Violation: The Avon 345/138 kV transformer #92 is
overloaded for line fault stuck breaker contingency loss of Avon –
Juniper 345 kV circuit and Avon 345/138 kV transformer #91
• Original Scope: At Avon 345 kV substation, replace the existing
345/138 kV 448 MVA #92 transformer with a 560 MVA unit
• Original Cost: $5.4M (Updated cost: $6.0M)
• Required IS date: 6/1/2019
• New Scope: Re-configure the existing Avon 345kV substation into a
breaker-and-a-half layout
• New Cost: $5.7M
• Reasons:
– The new configuration eliminates the contingency (stuck
breaker) causing the identified thermal overload.
– Eliminates the 345kV source, bus, and transformer loss at
Avon for the stuck breaker contingency.
– New layout provides increased operational flexibility including
transformer and breaker maintenance.
– Significant decrease in post contingency loading for the Avon
transformers as a result of the new configuration when
compared to the transformer replacement project.
– Provides reliability improvement for the broader BES Network
by eliminating the thermal violation.
– After additional engineering design and cost reviews, the cost
for the 345kV breaker configuration project is the least cost
planning alternative.
PJM TEAC – 6/8/2017 46 PJM©2017DEOK Transmission Zone
Common Mode Outage and Basecase Analysis
(Summer) (GD-S763, GD-S746, GD-S814, GD-S745, GD-
S813, N1-S91, N1-S92 and N1-S126):
Date Project Last Presented:10/12/2017 TEAC, 11/01/2017 TEAC
Problem Statement:
• The Pierce 345 /138kV transformer #18 is overloaded for the
loss of the Pierce 345/138kV transformer #17 with the breaker
stuck at Pierce.
• The Pierce 345 /138kV transformer #17 and the connected
Pierce –Beckjord 138kV circuit are overloaded for the loss of
the Pierce 345/138kV transformer #18 with the breaker stuck at
Pierce.
Alternatives considered:
2017_1-6A ($20.16M) :The two existing 345/138kV transformers
that connect Pierce 345kV Substation to Beckjord 138kV
Substation are fed radially. This project will Reconfigure Pierce
345kV Substation by adding new breakers, moving a feeder,
adding a third 345/138kV transformer, and feed the Pierce-
Beckjord transformers in a breaker and a half or double bus
configurations. The three transformer feeds will be distributed
across the three sets of buses at Beckjord.
2017_1-2E ($12.7 M): Build a 345 kV switching station
("Twelvemile") interconnecting the existing Silver Grove -
Zimmer 345 kV transmission line and the Pierce - Buffington 345
kV transmission line
Portion of 2017_1-6A ($9.17M): Reconfigure Pierce 345KV
substation and upgrade terminal equipment at Beckjord 138kV
on the Beckjord – Pierce 138kV line
Continued on the next slide…
PJM TEAC – 12/14/2017 47 PJM©2017DEOK Transmission Zone
Recommended Solution: (Portion of 2017_1-6A )
Install a new 345kV breaker “1422” so Pierce 345/138KV
transformer #18 is now fed in a double breaker, double bus
configuration. (B2977.1)
Remove X-533 No. 2 to the first tower outside the station. Install a
new first tower for X-533 No.2. (B2977.2)
Install new 345KV breaker B and move the Buffington-Pierce 345kV
feeder to the B-C junction. Install a new tower at the first tower
outside the station for Buffington-Pierce 345kV line. (B2977.3)
Remove breaker A and move the Pierce 345/138kV transformer #17
feed to the C-D junction. (B2977.4)
Replace breaker 822 at Beckjord 138kV substation to increase the
rating from Pierce to Beckjord 138kV to 603MVA. (B2977.5)
Estimated Project Cost: $ 9.17 M
Required IS date: 6/1/2021
Project Status: Conceptual
PJM TEAC – 12/14/2017 48 PJM©2017AEP Transmission Zone
Generation Deliverability (Winter) (GD-W92):
Date Project Last Presented: 10/12/2017 TEAC
Problem Statement:
• The Maddox – East Lima 345 kV line is
overloaded for the loss of the Marysville –
Sorenson 765KV line
Alternatives considered:
2017_1-8A ($1.48 M)
2017_1-8B ($111.64 M)
Recommended Solution :
• Replace terminal equipment on Maddox
Creek - East Lima 345kV circuit.
2017_1-8A. (B2969)
Estimated Project Cost: $ 1.48 M
Required IS date: 6/1/2022
Project Status: Conceptual
PJM TEAC – 11/2/2017 49 PJM©2017AEP/DEOK Transmission Zone
Generation Deliverability (Winter) (GD-W3,
GD-W5, GD-W6, GD-W7, and GD-W8):
Date Project Last Presented: 10/12/2017 TEAC
Problem Statement:
• The Tanner – Miami Fort 345 kV line is
overloaded for multiple single contingencies
Alternatives considered:
2017_1-7B ($19.32 M)
2017_1-7D ($55.09 M)
2017_1-7F ($11.45 M)
2017_1-8C ($1.2 M)
Recommended Solution :
• Upgrade existing 345kV terminal equipment
at Tanner Creek station. 2017_1-8C. (B2968)
Estimated Project Cost: $ 1.2 M
Required IS date: 6/1/2022
Project Status: Conceptual
PJM TEAC – 11/2/2017 50 PJM©2017ComEd Transmission Zone: Baseline
Schauff Road – Rock Falls 138KV Circuit
Baseline Reliability – Light Load Deliverability Violation
Previously presented: 9/11/2017 SRTEAC and
11/2/2017 SRTEAC
Problem Statement: Queue O-09 and O-29 are back to active
from suspension. Rock Falls – Nelson 138KV Red line, Schauff Road
(O09&O29) – Nelson Tap 138kV Red line and Schauff Road(O9&O29)
– Rock Falls 138kV Red line are overload in base case and multiple
single contingencies.
Immediate Need: Due to the immediate need, the timing required for
an RTEP proposal window is infeasible. As a result, the local
Transmission Owner will be the Designated Entity
Recommended Solution: Install a new 138kV circuit 18702
from Schauff Road to Rock Falls and install a fourth breaker and a
half run at Schauff Road. (B2959)
Estimated Cost: $20M
Expected In-service: 11/1/2019
SRRTEP - West - 11/02/2017 51 PJM©2017Planned Upgrades: Baseline Market Efficiency www.pjm.com PJM©2017
AEP 1-11B
Project ID: 201617_1-11B
Proposed by: AEP
Proposed Solution:
Accelerate the previously approved baseline project to
reconductor the Dequine-Eugene 345 kV and substation work
at Dequine.
(See approved baseline upgrade b2777)
kV Level: 345 kV
In-Service Cost ($M): 0, B/C Ratio >> 1.25 due to low cost
In-Service Date: 2019
Target Zone: AEP
ME Constraints:
EUGENE - DEQUIN 345 kV + RPM Benefits
Notes:
• CETL improvement of 1253 MW and very low cost
• Anticipate request for Board approval in Oct 2017
• Designated Entity: AEP (the local TO)
PJM TEAC – 8/10/2017 53 PJM©2017AEP1-11C
Project ID: 201617_1-11C
Proposed by: AEP
Proposed Solution:
Accelerate the previously approved baseline project to
reconductor the Dequine - Meadow Lake 345 kV #2 line and
substation work at Dequine.
(See approved baseline upgrade b2776)
kV Level: 345 kV
In-Service Cost ($M): 0, B/C Ratio >> 1.25 due to low cost
In-Service Date: 2019
Target Zone: AEP
ME Constraints:
DEQUIN - MEADOW 345 kV + RPM Benefits
Notes:
• CETL improvement of 1253 MW and very low cost
• Anticipate request for Board approval in Oct 2017
• Designated Entity: AEP (the local TO)
PJM TEAC – 8/10/2017 54 PJM©2017COMED 1-3A
Project ID: 201617_1-3A
Proposed by: ComEd
Proposed Solution:
Upgrade capacity on E. Frankfort - University Park 345 kV line.
kV Level: 345 kV
In-Service Cost ($M): $0.84, B/C Ratio =147.69
In-Service Date: 2021
Target Zone: ComEd
ME Constraints:
E. FRANKFORT - UNIVERSITY PARK 345 kV + RPM Benefits
Notes:
• CETL improvement of 772 MW and very low cost
• Anticipate request for Board approval in Oct 2017
• Designated Entity: ComEd (the local TO)
• Cost Allocation: 100% ComEd
PJM TEAC – 8/10/2017 55 PJM©2017COMED 1-3B
Project ID: 201617_1-3B
Proposed by: ComEd
Proposed Solution:
Upgrade substation equipment at Pontiac Midpoint station to
increase capacity on Pontiac-Brokaw 345 kV line.
kV Level: 345 kV
In-Service Cost ($M): $5.62, B/C Ratio =13.45
In-Service Date: 2021
Target Zone: ComEd
ME Constraints:
PONTIAC - BROKAW 345 kV + RPM Benefits
Notes:
• CETL improvement of 339 MW and low cost
• Anticipate request for Board approval in Oct 2017
• Designated Entity: ComEd (the local TO)
• Cost Allocation: 100% ComEd
PJM TEAC – 8/10/2017 56 PJM©2017PJM_RPM_DEOK
Project ID: 201617_PJM_RPM_DEOK
Proposed by: PJM
Proposed Solution:
Replace terminal equipment at Tanners Creek on Tanners
Creek - Dearborn 345 kV line.
kV Level: 345 kV
In-Service Cost ($M): $0.5, B/C Ratio >> 1.25 due to low cost
In-Service Date: 2021
Target Zone: DEOK
ME Constraints:
TANNERS CREEK - MIAMI FORT 345 kV
Notes:
• CETL improvement of 332 MW and very low cost
• Anticipate request for Board approval in Oct 2017
• Designated Entity: AEP (the local TO)
• Cost Allocation: TBD
PJM TEAC – 8/10/2017 57 PJM©2017201617_1A-2A
Project ID: 201617_1A-2A
Proposed by: American Electric Power (AEP)
Proposed Solution: Upgrade
Upgrade terminal equipment at Tanners Creek 345kV station
Upgrade 345kV Bus and Risers at Tanners Creek for the
Dearborn circuit.
kV Level: 345 kV
In-Service Cost ($M): $0.6, B/C Ratio = 151.61
In-Service Date: 6/1/2021
Target Zone: DEOK LDA
ME Constraints:
TANNERS CREEK - MIAMI FORT 345 kV
Notes:
• Very low cost
• Anticipate recommendation for Board approval in
December 2017
• Designated Entity: AEP (the local TO)
58 PJM©2017
PJM TEAC – 11/2/2017Planned Upgrades: Supplemental www.pjm.com PJM©2017
ComEd Transmission Area
Supplemental Project
Previously Presented: Dec. 15, 2016
Problem Statement:
• 765 kV line 11215 from Wilton Center to Dumont has a 150 MVAR
shunt inductor at Wilton Center and a 300 MVAR shunt inductor at
Dumont in AEP. The AEP inductor will have a circuit breaker
installed under b2231 (Install 765 kV reactor breaker at Dumont 765
kV substation on the Dumont - Wilton Center line).
• The Wilton Center inductor is bolted to the line with no switching
device.
• This line has a large impact on the PJM market.
• The inductor is removed in summer months for voltage support and
returned to service in the fall. Each time it is switched requires a day
long outage to bolt or unbolt the connections.
• Installing a CB on the inductor will have several benefits:
– No more line outages required for seasonal switching.
– The inductor can be switched in and out as conditions
change instead of being switched seasonally
– The inductor will automatically close in the event of a high
voltage condition.
– Line will stay in service for inductor faults
Selected Solution:
Install 765 kV CB at Wilton Center 765kV substation on line 11215 (Wilton
Center – Dumont 765kV line) shunt inductor (S1204)
Estimated Project Cost: $5.8M
Projected IS Date: 6/1/2018
Project Status: Engineering & Procurement
www.pjm.com 60 PJM©2017ComEd Transmission Area
Supplemental Project
Previously Presented: Dec. 15, 2016
Problem Statement:
• Presently Pontiac transformer 82 shares a 345 kV
ring bus position with 345 kV line 8014 (Pontiac –
Dresden).
– There is no high-side circuit breaker on
transformer 82, so any transformer fault
trips line 8014.
– The line must be switched out of service to
switch the transformer off.
– A line fault on 8014 trips transformer 82.
Selected Solution:
At Pontiac 345kV station, install 345 kV bus tie 6-7 to
separate the transformer and line onto their own bus
sections and Install a high side circuit breaker on
transformer 82 to bring it up to current standards.
(S1205)
Estimated Project Cost: $4.1M
Projected IS Date: 12/31/2018
Project Status: Engineering & Procurement
www.pjm.com 61 PJM©2017ComEd Transmission Area
Supplemental Project
Previously Presented: Dec. 15, 2016
Problem Statement:
• Presently Pontiac transformer 82 shares a 345 kV
ring bus position with 345 kV line 8014 (Pontiac –
Dresden).
– There is no high-side circuit breaker on
transformer 82, so any transformer fault
trips line 8014.
– The line must be switched out of service to
switch the transformer off.
– A line fault on 8014 trips transformer 82.
Selected Solution:
At Pontiac 345kV station, install 345 kV bus tie 6-7 to
separate the transformer and line onto their own bus
sections and Install a high side circuit breaker on
transformer 82 to bring it up to current standards.
(S1205)
Estimated Project Cost: $4.1M
Projected IS Date: 12/31/2018
Project Status: Engineering & Procurement
www.pjm.com 62 PJM©2017DEOK Transmission Zone
Supplemental Project: - Remove
Beckjord U6 Feeder
Problem Statement/Driver:
Beckjord Unit 6 was retired October 2014. The GSU has
been removed. The connecting 345kV feeder from the GSU
to Pierce substation is no longer in use and crosses over a
state highway. The single support tower and the feeder are
over fifty years old and in declining condition. Need to
remove the risk of the feeder falling onto the highway.
Potential Solution:
Remove 345kV feeder and support tower.
Alternatives: No alternatives.
Cost Estimate: $0.121M
Projected IS date: 12/31/2017
Status: Planning
PJM TEAC – 4/13/2017 63 PJM©2017Dominion Transmission Area
Supplemental Project: Reeves Ave Station
Problem Statement: Operational Performance
• Reeves Ave 230kV configuration: 230/115kV transformers #4 and #5 are hung off 230kV
line #279 and #2038 respectively with sectionalizing schemes
o Fault on the 230kV lines remove network transformer, and fault on transformers trip
corresponding line, interrupting the network and any tapped load.
o Breaker maintenance on the 230kV tie breaker opens the 230kV network.
• Reeves Ave 115kV configuration: 115/34.5kV transformer #6 is hung off 115kV line #94
with sectionalizing scheme, 115/34.5kV transformer #2 and #3 connect to 115kV bus #2
and #1 respectively with sectionalizing schemes, multiple 115kV lines connect to
corresponding bus with breakers.
o Fault on line #94 removes transformer #6 affecting about 3000 customers, fault on
transformer #6 trips line #94, interrupting the network.
o Fault on transformer #2 or #3 will trip all 115kV lines associated with corresponding
bus, interrupting the network.
PJM TEAC – 4/13/2017 64 PJM©2017AEP Transmission Zone: Supplemental
Kenzie Creek Breaker Addition
Supplemental Project
Previously Presented: 11/9/2017 TEAC
Problem Statement:
Operational Flexibility and Efficiency
Motor Operated Air Break Switches (MOABs) have been utilized in the past as a
less costly alternate to Circuit Breakers. MOABs at Extra High Voltage (EVH)
unnecessarily subject expensive equipment, such as Transformers, to grid events
in order to isolate a faulted section of the grid. This not only reduces the life of
such expensive equipment, but also results in misoperations. It is AEP’s practice
to not install MOABs for fault sectionalizing at EHV. In addition, AEP is proactively
replacing all EHV MOABs at existing stations with circuit breakers.
Selected Solution:
At Kenzie Creek station, retire 345kV MOABS ‘W’ and ‘Y’. Install 3 345kV 5000A
63kA breakers in a ring bus configuration. Set up station to allow for future ‘B’
and ‘C’ breaker strings. (S1448)
Estimated Transmission Cost: $7.4M
Projected In-service: 12/31/2018
Project Status: Engineering
PJM TEAC – 12/14/2017 65 PJM©2017AEP Transmission Zone: Supplemental
Desoto Breaker Replacement
Supplemental Project
Previously Presented: 11/9/2017 TEAC
Problem Statement:
Equipment Material/Condition/Performance/Risk:
At Desoto station, breaker C is an FX22A 3000A 50 kA Hydraulic breaker from
1985. Although only 32 years old, this breaker has experienced 124 fault
operations which is significantly higher than the manufacturer recommendation of
3. In addition to this, there has been a rising trend of gas pressure on this breaker.
Due to these identified issues, AEP recommends replacement of this breaker.
Selected Solution:
Replace 345kV breaker C with a GE Alstom 5000A 63kA 345kV breaker (S1450)
Estimated Transmission Cost: $1.0M
Projected In-service: 12/29/2017
Project Status: Construction
PJM TEAC – 12/14/2017 66 PJM©2017You can also read
