Transmission Expansion Advisory Committee (TEAC) Recommendations to the PJM Board

Transcription

1 Transmission Expansion Advisory Committee (TEAC) Recommendations to the PJM Board PJM Staff Whitepaper October 2013

2 EXECUTIVE SUMMARY On December 5, 2012 the PJM Board of Managers approved changes to the Regional Transmission Expansion Plan (RTEP), totaling $1,781.3 million, primarily to resolve identified baseline reliability criteria violations as well as to address reliability criteria violations driven by the proposed interconnection of new generation resources. Since that time PJM has identified additional baseline reliability criteria violations within the planning horizon as part of the 2013 RTEP. Transmission upgrades have been identified to resolve these reliability criteria violations. In addition, the cost and scope of a number of previously approved projects has changed. The total increase to the RTEP to include these baseline project changes is $1,241.1 million. With these changes, the RTEP will include over $24.2 billion of transmission additions and upgrades since the first plan was approved by the Board in The additional baseline upgrades that were reviewed with the PJM Board are summarized in the following paper. PJM 2013 Page 1 of 21 PJM DMS #768430

3 SUMMARY OF UPGRADES 2013 Baseline Transmission Upgrades Changes and Additions One aspect of the development of the Regional Transmission Expansion Planning Process is an evaluation of the baseline system, i.e. the transmission system without any of the generation interconnection requests included in the current planning cycle. This baseline analysis determines the compliance of the existing system with reliability criteria and standards. Transmission upgrades required to maintain a reliable system are identified and reviewed with the Transmission Expansion Advisory Committee (TEAC). The cost of transmission upgrades to mitigate such criteria violations are the responsibility of the PJM transmission owners. For the 2013 Plan, the baseline assessment resulted in the need for transmission upgrades in several transmission zones. A summary of the more significant baseline projects with expected costs greater than $5 million are detailed below. A complete listing of all of the new recommended projects is attached at the end of this white paper. The projects that cost less than $5 million include circuit breaker upgrades or replacements to address short circuit problems, new or upgrades to existing capacitor banks to address voltage violations, terminal equipment upgrades and conductor replacements to increase the ratings of transmission lines to address thermal violations. Mid-Atlantic Region System Upgrades Atlantic Electric Transmission Zone Upgrade the Tackahoe to Mill 69 kv line $9.9 M Install a 50 MVAR shunt reactor at Mickleton 230 kv and relocate the #1 230/69 kv transformer - $7.6 M Install a +150/-100 MVAR SVC at Cedar 230 kv - $23.2 M Rebuild 9.7 miles of the Upper Pittsgrove Landis 138 kv line and upgrade terminal equipment at Landis - $11.2 M BG&E Transmission Zone Install four 115 kv breakers at Chestnut Hill - $6.4 M Install a new 230/115 kv transformer at Raphael Road and build 115 kv line from Rpahael Road to Joppatowne - $35 M Build a new 115 kv underground line between Waugh Chapel and Bestgate - $27.2 M DPL Transmission Zone Build a new 138 kv line from Piney Grove to Wattsville - $16.3 M JCPL Transmission Zone Install a 260 MVAR shunt reactor at West Wharton 230 kv - $8 M PENELEC Transmission Zone Relocate substation controls from the deactivating Shawville generating station to a new substation control building - $6.7 M PJM 2013 Page 2 of 21 PJM DMS #768430

4 PEPCO Transmission Zone Add two 100 MVAR reactors at Dickerson Station H and two 100 MVAR reactors at Brighton 230 kv - $16 M PPL Transmission Zone Add a second 150 MVA 230/69 kv transformer at Springfield - $6.7 M Add a 150 MVAR shunt reactor at Alburtis 500 kv - $9 M Add a 100 MVAR shunt reactor at Elimsport - $6.5 M Rebuild Susquehanna Jenkins 230 kv circuit $109.5 M Rebuild the Siegfried Frackville 230 kv circuit - $84.5 M PSEG Transmission Zone Rebuild 4 miles of overhead line from Edison Meadow Rd Metuchen (Q-1317) - $46 M Install a 50 MVAR shunt reactor at Saddlebrook 230 kv - $9.2 M Install a 50 MVAR shunt reactor at Athenia 230 kv - $8.4 M Install a 50 MVAR shunt reactor at Bergen 230 kv - $8.3 M Install a 50 MVAR shunt reactor at Hudson 230 kv - $7.9 M Install two 50 MVAR shunt reactor at Stanley Terrace 230 kv - $15.7 M Install a 50 MVAR shunt reactor at West Orange 230 kv - $8.7 M Install a 50 MVAR shunt reactor at Aldene 230 kv - $6.9 M Install a 150 MVAR shunt reactor at Camden 230 kv - $8.3 M Install a 150 MVAR shunt reactor at Gloucester 230 kv - $7.8 M Install a 50 MVAR shunt reactor at Clarksville 230 kv - $7.2 M Install a 50 MVAR shunt reactor at Hinchmans 230 kv - $10 M Install a 50 MVAR shunt reactor at Beaverbrook 230 kv - $7 M Install a 50 MVAR shunt reactor at Cox s Corner 230 kv - $7 M Reconfigure the Sewaren 230 kv; Convert the two 138 kv circuits from Sewaren Metuchen to 230 kv circuits including Lafayette and Woodbridge substation; Reconfigure the Metuchen 230 kv station to accommodate the two converted circuits - $101 M Western Region System Upgrades AEP Transmission Zone Reconductor the AEP portion of the Cloverdale Lexington 500 kv line - $40 M Install a 300 MVAR shunt reactor at Dequine 345 kv - $8 M Replace the 150 MVAR shunt reactor at Amos on the Amos to Hanging Rock 765 kv line with a 300 MVAR shunt reactor - $5 M Rebuild the Corner to Degussa 138 kv line - $7.5 M Upgrade the 138 kv line between Harrison and Ross - $40.5 M Rebuild the Pokagon Corey 69 kv line at a double circuit 138 kv line - $65 M Install a new 138/69 kv transformer at George Washington - $7 M Build a new 138/12 kv substation near Nicholsville; Tap the Hydramatic Valley 138 kv circuit (~ structure 415), build a new 138 kv line (~3.75 miles) to this new station; From this station, construct a new 138 kv line (~1.95 miles) to REA s Marcellus station; From REA s Marcellus station construct new 138 kv line (~2.35 miles) to a tap point on Valley Hydramactic 138 kv ckt (~structure 434); Retire sections of the 138 kv line in between structure 415 and 434 (~ 2.65 miles); Retire AEP s Marcellus 34.5/12 kv and Nicholsville 34.5/12 kv stations and also the Marcellus Valley 34.5 kv line - $30 M PJM 2013 Page 3 of 21 PJM DMS #768430

5 Build a new 69 kv line from Hartford to Keeler ; Rebuild the 34.5 kv lines between Keeler - Sister Lakes and Glenwood tap switch to 69 kv (~12 miles); Implement in - out at Keeler and Sister Lakes 34.5kV stations; Retire Glenwood tap switch and construct a new Rothadew station. These new lines will continue to operate at 34.5 kv - $30 M Rebuild the North Delphos to S kv line and upgrade terminal equipment - $22.4 M Build a new 138 kv line from Richlands Station to the intersection of the Hales Branch to Grassy Creek 138 kv line - $28 M APS Transmission Zone Install a 250 MVAR SVC at Squab Hollow 230 kv - $33.5 M Reconfigure the Lake Lynn Lardin 138 kv circuits - $22.9 M Convert the Shingletown 230 kv bus to a six breaker ring bus - $5.5 M Install a 230/138 kv transformer at Squab Hollow and loop the Forest Elko 230 kv line into Squab Hollow and loop the Brookville Elko 138 kv line into Squab Hollow - $16.8 M ATSI Transmission Zone Reconductor the ATSI portion of Howard Brookside 138 kv line - $7.75 M Duquesne Transmission Zone Install a 200 MVAR shunt reactor at Brunot Island 345 kv - $8.65 M Install a 200 MVAR shunt reactor on the future Brunot Island Carson underground 345 kv line - $8.65 M EKPC Transmission Zone Build a new 69 kv line from Mercer County Industrial to Van Arsdell Substation; Construct a new 69 kv switching station ("South Anderson") adjacent to the LGE/KU Bonds Mill substation; Loop the North Springfield - Van Arsdell 69 kv line through South Anderson. Terminate the existing 69 kv to the LGE/KU Bonds Mill substation at South Anderson and establish a second 69 kv from S. Anderson to the LGE/KU Bonds Mill sub; Construct 0.12 miles of 69 kv line from South Anderson to the Powell Taylor distribution substation and serve this substation radially from South Anderson - $6.64 M Southern Region System Upgrades Dominion Transmission Zone Build a new 230 kv line from Dooms to Lexington on existing ROW - $35 M Construct a new 230 kv line from Idylwood to Dulles Toll Road - $32 M PJM 2013 Page 4 of 21 PJM DMS #768430

6 Rebuild the Susquehanna Jenkins 230 kv Line The Susquehanna Jenkins 230 kv, line located in the PP&L transmission zone, is overloaded for several NERC category C3 contingency combinations as well as for the generation deliverability test. A NERC category C3 contingency is a single contingency followed by system adjustments to return all facilities below their normal rating, followed by the loss of a second single contingency. These types of events are often referred to as N-1-1 events. There are several contingency pairs driving the criteria violation on the Susquehanna Jenkins 230 kv. The recommended solution to address the overload is to rebuild the line using a larger conductor. The existing conductor is a 1033 ACSR. The new conductor will be 1590 ACSR. The existing structures will not meet current design standards with the larger conductor and as a result will need to be replaced as part of the scope of this project. The estimated cost for the project is $109.5 million and is expected to be completed by June 1, PJM 2013 Page 5 of 21 PJM DMS #768430

7 Rebuild the Siegfried Frackville 230 kv Line The Siegfried Frackville 230 kv line is overloaded for the loss of the two Montour to Susquehanna 230 kv lines. The Montour Susquehanna 230 kv lines are built on a double circuit tower-line between the two stations. The overload resulting from the loss of the double circuit tower-line is a NERC category C violation. The recommended solution to address the overload is to rebuild the line using a larger conductor. The existing conductor is a 1033 ACSR. The new conductor will be 1590 ACSR. The existing structures will not meet current design standards with the larger conductor and as a result will need to be replaced as part of the scope of this project. The estimated cost for the project is $84.5 million and is expected to be completed by June 1, PJM 2013 Page 6 of 21 PJM DMS #768430

8 Reconfigure the Sewaren Substation The existing Sewaren substation in the PSE&G transmission zone will be reconfigured to address aging infrastructure concerns as well as to address short circuit problems on the 138 kv system. The proposed solution will eliminate the 138 kv bus by converting the two Metuchen to Sewaren 138 kv circuits to 230 kv. In addition to addressing aging infrastructure concerns the project will also address substation vulnerabilities that were hi-lighted during super storm Sandy. The estimated cost of the project is $101 million and is expected to be completed by June 1, PJM 2013 Page 7 of 21 PJM DMS #768430

9 Convert the Pokagon Corey 69 kv line to a Double Circuit 138 kv line The 2013 RTEP identified a number of low voltage and voltage drop violations on several 138 kv busses in the Michigan portion of the AEP transmission zone. The voltage violations are due to the N-1-1 loss of the Corey to Mottsville to East Elkhart 138 kv line followed by the loss of the Bushz to Flowerfield to Valley 138 kv line. The recommended solution to address this NERC category C3 violation is to rebuild the existing Pokagon Corey 69 kv line as a 138 kv double circuit line between Pokagon and Corey. The estimated cost for this upgrade is $65 million and the required in-service date is June 1, PJM 2013 Page 8 of 21 PJM DMS #768430

10 High Voltage in Real-Time Operations The incidence of high voltage alarms during the valley load period have been increasing and are becoming more difficult for operating personnel to manage. The high voltage conditions are being driven by a number of factors including new transmission that has been built to address thermal violations during peak load conditions as well as changes in generation dispatch patterns resulting from the cost of gas resources relative to coal fired resources. System operators have been managing the high voltage conditions by switching off shunt capacitors and adjusting the reactive output of on-line generation. In some cases, these actions have not been sufficient and operators have been forced to switch lightly loaded transmission lines out of service. The map below shows the areas of the system where the high voltage alarms are most common. As part of the 2013 RTEP PJM staff has developed transmission upgrades to address the high voltage conditions. Historical alarm data was reviewed to identify the locations on the system where the problems are most prevalent. Light load power-flow cases were developed based on energy management system snapshots of the system to simulate the conditions seen in real-time operations. Locations were identified where switchable shunt reactive devices could be installed to address the high voltage conditions. The table on the following page summarizes the location, cost and expected in-service date of the shunt reactive devices that are being recommended to address the high voltage conditions. PJM 2013 Page 9 of 21 PJM DMS #768430

11 Upgrade ID Description TO Presented by PJM Staff to the Board Reliability Committee In Service Date Cost Estimate ($M) b MVAR shunt reactor at Brunot Island 345 kv DL 6/1/ MVAR shunt reactor on future Brunot Island b Carson 345 kv circuit DL 6/1/ b2229 Install a 300 MVAR reactor at Dequine 345 kv AEP 12/1/ b2230 b2231 b2232 b2233 Replace existing 150 MVAR reactor at Amos 765 kv substation on Amos N. Proctorville - Hanging Rock with 300 MVAR reactor AEP 6/1/ Install 765 kv reactor breaker at Dumont 765 kv substation on the Dumont - Wilton Center line AEP 12/1/ Install 765 kv reactor breaker at Marysville 765 kv substation on the Marysville - Maliszewski line AEP 6/1/ Change transformer tap settings for the Baker 765/345 kv transformer AEP 6/1/ b MVAR reactor at Monocacy 230 kv APS 6/1/ b MVAR shunt reactor at Mickleton 230 kv and relocate Mickleton # kv transformer AEC 6/1/ b /-100 MVAR SVC at Cedar 230 kv AEC 6/1/ b2234 2x130 MVAR reactor at West Wharton 230 kv JCPL 4/1/ b MVAR reactor at Buckingham 230 kv PECO 12/31/ b MVAR shunt reactor at Alburtis 500 kv PPL 6/1/ b MVAR shunt reactor at Elimsport 230 kv PPL 6/1/ b2279 Add two 100 MVAR reactors at Dickerson Station H and two 100 MVAR reactors at Brighton 230 kv substation PEPCO 6/1/ b MVAR reactor at Saddlebrook 230 kv PSEG 6/1/ b MVAR reactor at Athenia 230 kv PSEG 6/1/ b MVAR reactor at Bergen 230 kv PSEG 6/1/ b MVAR reactor at Hudson 230 kv PSEG 6/1/ b2243 Two 50 MVAR reactors at Stanley Tce 230 kv PSEG 6/1/ b MVAR reactor at West Orange 230 kv PSEG 6/1/ b MVAR reactor at Aldene 230 kv PSEG 6/1/ b MVAR reactor at Camden 230 kv PSEG 6/1/ b MVAR reactor at Gloucester 230 kv PSEG 6/1/ b MVAR reactor at Clarksville 230 kv PSEG 6/1/ b MVAR reactor at Hinchmans 230 kv PSEG 6/1/ b MVAR reactor at Beaverbrook 230 kv PSEG 6/1/ b MVAR reactor at Cox's Corner 230 kv PSEG 6/1/ PJM 2013 Page 10 of 21 PJM DMS #768430

12 Changes to Previously Approved Projects Cost and scope of a number of previously approved RTEP baseline projects have been updated. In addition, a number or projects have been cancelled as they are no longer required. The net result to these changes to previously approved baseline projects is a net increase in the RTEP of $19.7 million. Review by the Transmission Expansion Advisory Committee (TEAC) The results of the analyses summarized in this report were reviewed with the TEAC and Subregional RTEP Committees over several meetings throughout The most recent analysis, along with recommended solution, was reviewed at the September 12, 2013 meeting. Written comments were requested to be submitted to PJM communicating any concerns with the recommendation and any alternative transmission solutions for consideration. As of the writing of this report there have been no comments received on the projects presented to the TEAC. Cost Allocation On October 11, 2012 the PJM Transmission Owners, filed proposed tariff revisions to Schedule 12 of the OATT to modify the methods used for the allocation of costs of transmission upgrades approved pursuant to the RTEP. In an Order issued on January 31, 2013, the FERC conditionally accepted and nominally suspended the proposed cost allocation methods for filing, to be effective February 1, 2013 subject to refund and to a future order in PJM s Order 1000 compliance filing. On July 22, 2013, the PJM Transmission Owners submitted their 2 nd Order No compliance filing in response to the March 22, 2013 Order. A FERC order has yet to be issued on this second compliance filing. Similar to the previous method, the new cost allocation methodology for baseline reliability upgrades has a definition of Regional Facilities that includes A.C. facilities operated at 500 kv or above. In addition it also now includes two A.C. circuits between the same two substations operated at 345 kv and above but less than 500 kv (e.g. 345 kv double circuit towerline). Under the new methodology the cost allocation for Regional Facilities would be assigned 50% on a load ratio share basis and 50% on a use based distribution factor methodology. The cost allocation for lower voltage facilities (i.e. 345 kv single circuit and below) would be based entirely on the use based distribution factor methodology. As was the case with the previous cost allocation method, baseline reliability projects that are expected to cost less than $5 million are allocated entirely to the transmission zone that they are located in. The use based distribution factor methodology is similar to the previous violation based distribution factor methodology in that both use power-flow software to calculate the impact of the load of a transmission zone on a facility. However the cost allocation for a baseline reliability upgrade using the new use based distribution factor methodology is based on the contribution of a transmission zone load to the loading on the new transmission facility. Recall the cost allocation for baseline reliability upgrades under the violation based distribution factor was based on the contribution of a transmission zone to the loading on the overloaded facility (i.e. the facility with the violation) and not the new facility being added to address the overload. PJM 2013 Page 11 of 21 PJM DMS #768430

13 Pursuant to FERC order, the allocations for the recommended baseline reliability upgrades will be developed using the new use based allocation methodology. Board Approval The PJM Board approved all of the recommendations to the 2013 RTEP. PJM 2013 Page 12 of 21 PJM DMS #768430

14 Appendix RTEP Baseline Upgrade Cost Allocation Single Zone Allocations Presented by PJM Staff to the Board Reliability Committee PJM 2013 Page 13 of 21 PJM DMS #768430

15 Appendix RTEP Baseline Upgrade Cost Allocation continued Presented by PJM Staff to the Board Reliability Committee PJM 2013 Page 14 of 21 PJM DMS #768430

16 Appendix RTEP Baseline Upgrade Cost Allocation continued Presented by PJM Staff to the Board Reliability Committee PJM 2013 Page 15 of 21 PJM DMS #768430

17 Appendix RTEP Baseline Upgrade Cost Allocation continued PJM 2013 Page 16 of 21 PJM DMS #768430

18 Appendix RTEP Baseline Upgrade Cost Allocation continued PJM 2013 Page 17 of 21 PJM DMS #768430

19 Appendix RTEP Baseline Upgrade Cost Allocation continued PJM 2013 Page 18 of 21 PJM DMS #768430

20 Appendix RTEP Baseline Upgrade Cost Allocation continued PJM 2013 Page 19 of 21 PJM DMS #768430

21 Appendix RTEP Baseline Upgrade Cost Allocation continued PJM 2013 Page 20 of 21 PJM DMS #768430

22 Appendix RTEP Baseline Upgrade Cost Allocation continued Multiple Zone Allocations PJM 2013 Page 21 of 21 PJM DMS #768430