FACILITIES STUDY ICTT TRANSMISSION SERVICE FACILITIES STUDY OASIS

Transcription

1 TRANSMISSION LINE & SUBSTATION PROJECTS COMPANY: ENTERGY SERVICES, INC. CUSTOMER: EAST TEXAS ELECTRIC COOPERATIVE (ETEC) FACILITIES STUDY EJO NO. F4PPTX0068 ICTT TRANSMISSION SERVICE FACILITIES STUDY OASIS Rev Issue Date Revision: 0 Description of Revision Prepared By Approved By A 06/20/11 Shell for team input IK ED B 07/06/11 Submitted for JET vote IK ED C 07/13/11 Final submission to PD IK ED D 08/01/11 Revised based on Kevin Schultz comments 0 08/05/11 ICT Determines Upgrade Classification IK Sherri Maxey ED Ben Roubique

2 TABLE OF CONTENTS 1. PROJECT SUMMARY Background and Project Need Scope Summary Cost Summary Schedule Summary SAFETY REQUIREMENTS GENERAL ASSUMPTIONS SCOPE OF WORK New Quarry Substation Rivtrin Substation Grimes Substation (relating to line cut-in) Crockett Substation (Owned by AEP/SWEPCO) Pee Dee Substation Lewis Creek Huntsville New 345 kv line L831 between Rivtrin and new Quarry SS Line cut-in into Quarry 345 kv SS (line from Grimes) Line cut-in into Quarry 345 kv SS (line from Crockett) Transmission Line Work at Rivtrin Substation Mt. Zion to Grimes 138 kv new line Upgrade the Toledo Bend-Leach 138 kv transmission line Toledo Bend 138 kv Replace line bay bus Upgrade Newton Bulk-Leach 138 kv transmission line Upgrade the Rayburn - Jasper 138 kv transmission line Upgrade Huntsville-Wyntex Tap (L558TP91) 138 kv transmission line COST UPGRADE CLASSIFICATION SCHEDULE RISK ASSESSMENT

3 9. CONFIRMED RESERVATIONS PRE-888 TRANSACTIONS STUDY QUEUE ATTACHMENTS Table of Acronyms Duration Schedule

4 1. PROJECT SUMMARY 1.1 Background and Project Need The purpose of this Facilities Study is to determine the availability of transfer capability across Entergy s transmission system from American Electric Power (CSWS) to East Texas Electric Cooperative (ETEC) to evaluate the ETEC request for 125 MW of yearly network transmission service. The time period for this transfer is from 1/1/2015 until 1/1/2020. The direction of the transaction is CSWS to ETEC. The study was performed on the latest available winter and summer peak seasonal models using PSS/E and MUST software by PTI. The Facilities Study identifies any transmission constraints resulting from the requested power transfer. The Facilities Study also includes cost estimates to correct any transmission constraints. 1.2 Scope Summary The constraints can be addressed in the following manner: Construct a new 345 kv substation; build a new 345 kv line from the new 345 kv substation to Rivtrin 138 kv substation, and install 345/138 kv autotransformer at Rivtrin The following constraints are observed for this transmission service request: Limiting Element Contingency Element Grimes Bentwater - Walden 138 kv Mt. Zion - Wyntex Tap - Huntsville 138 kv Cypress - Hartburg 500kV Tubular - Dobbin 138 kv Grimes Bentwater - Walden 138 kv Grimes - Mt. Zion - Wyntex Tap - Huntsville 138 kv Grimes Bentwater Walden April - Lake Forest Mt. Zion - Wyntex Tap - Huntsville 138 kv Woodhaven - Conroe 138 kv Grimes - Bentwater 138 kv Hartburg - Mt. Olive 500 kv Mt. Zion - Wyntex Tap - Huntsville 138 kv Mt. Zion - Wyntex Tap 138 kv Grimes - Magnolia Anderson 138 kv Grimes - College Station 138 kv Magnolia Anderson - Sota 138 kv Grimes - Bentwater 138 kv China - Amelia 230 kv Mt. Zion - Wyntex Tap 138 kv Mt. Zion - Wyntex Tap 138 kv Mt. Olive - El Dorado 500 kv Mt. Zion - Wyntex Tap 138 kv Hartburg - Cottonwood 500 kv #1 or #2 4

5 Mt. Zion - Wyntex Tap 138 kv Nelson Unit #6 Mt. Zion - Wyntex Tap 138 kv Nelson Unit #4 Mt. Zion - Wyntex Tap 138 kv Sabine Unit #4 Mt. Zion - Wyntex Tap 138 kv Cypress 500/138 kv autotransformer Grimes - Magnolia Anderson Sota - Navasota Mt. Zion - Wyntex Tap 138 kv 138 kv Grimes - Bentwater 138 kv China - Porter 230 kv Mt. Zion - Wyntex Tap - Huntsville 138 kv Bryan - College Station 138 kv Mt. Zion - Wyntex Tap 138 kv Cypress - Honey 138 kv Mt. Zion - Wyntex Tap 138 kv Honey Bragg - Menard 138 kv Mt. Zion - Wyntex Tap 138 kv Bryan - Pee Dee 138 kv Mt. Zion - Wyntex Tap 138 kv Menard - Gulf Livingston - Poco 138 kv Mt. Zion - Wyntex Tap 138 kv China - Jacinto 230 kv Mt. Zion - Wyntex Tap 138 kv Navasota - Longmire 138 kv Mt. Zion - Wyntex Tap 138 kv Corrigan - Doucette 138 kv Grimes 345/138 kv autotransformer #1/#2 Grimes 345/138 kv autotransformer #2/#1 Kountze - Lumberton 138 kv Cypress Bevil - Amelia 230 kv It is required that the following project be constructed: New substation: Build a new 345 kv three (3) terminal substation. Re-route the Grimes - Crockett 345 kv transmission line into the new three (3) breaker ring switchyard; connecting the Grimes and Crockett 345 kv substations to the new switchyard. Rivtrin Install a 600MVA, 345/138 kv autotransformer. The amount of capacity created by this upgrade is 600 MW, and the customer s use of the capacity created is 23 MW. Build a new 345 kv line from Rivtrin 345 kv to the new substation. The amount of capacity created by this upgrade is 1300 MW, and the customer s use of the capacity created is 23 MW Upgrade Grimes - Mt. Zion 138 kv transmission line; AEP Affected System Study The Grimes - Mt. Zion 138 kv transmission line overloads for the loss of the Quarry - Rivtrin 345 kv transmission line. It is required that the Grimes - Mt. 5

6 Zion 138 kv transmission line be upgraded from a capacity of 206 MVA to at least 218 MVA. The proposed upgrade is 260 MVA. The amount of capacity created by this upgrade is 54 MW, and the customer s use of the capacity created is 12 MW. The Grimes - Mt. Zion 138 kv line upgrade has been identified as a required upgrade in prior Facilities Studies (OASIS requests , , , , and ASA /-002/-003/-004/-005). Should the transmission customers in the referenced requests commit to this upgrade, then ETEC may be responsible for financial payments pursuant to Attachment T to Entergy s OATT. If any of the prior transmission service requests (OASIS requests , , , , or ASA /-002/-003/-004/-005) are withdrawn, then ETEC would be responsible for this upgrade Upgrade Toledo Bend - Leach 138 kv transmission line The Toledo Bend - Leach 138 kv transmission line overloads for the loss of the Quarry - Rivtrin 345 kv or Quarry - Crockett 345 kv transmission line. The Toledo Bend - Leach 138 kv transmission line needs to have a capacity of 178 MVA or greater on all components. The equipment at Toledo Bend needs to be upgraded to increase the rating of the transmission line from 134 MVA to 143 MVA. The upgrade of the Toledo Bend equipment (which increases the line rating to 143 MVA) is proposed in the Entergy Construction Plan with a 2013 Expected ISD. It is required that the Toledo Bend - Leach 138 kv transmission line be upgraded from a capacity of 143 MVA to at least 178 MVA. The proposed upgrade is 211 MVA. The amount of capacity created by this upgrade is 68 MW, and the customer s use of the capacity created is 10 MW. The Toledo Bend - Leach 138 kv line upgrade has been identified as a required upgrade in a prior Facilities Study (OASIS request ). Should the transmission customer in the referenced requests commit to this upgrade, then ETEC may be responsible for financial payments pursuant to Attachment T to Entergy s OATT. If the prior transmission service request (OASIS request ) is withdrawn, then ETEC would be responsible for this upgrade Upgrade Newton Bulk - Leach 138 kv transmission line The Newton Bulk - Leach 138 kv transmission line overloads for the loss of the Quarry - Crockett 345 kv transmission line. The Newton Bulk - Leach 6

7 138 kv transmission line needs to have a capacity of 175 MVA or greater on all components. The equipment at Newton Bulk needs to be upgraded to increase the rating of the transmission line from 141 MVA to 143 MVA. The upgrade of the Newton Bulk equipment (which increases the line rating to 143 MVA) is proposed in the Entergy Construction Plan with a 2013 Expected ISD. It is required that the Newton Bulk - Leach 138 kv transmission line be upgraded from a capacity of 143 MVA to at least 175 MVA. The proposed upgrade is 211 MVA. The amount of capacity created by this upgrade is 68 MW, and the customer s use of the capacity created is 10 MW. The Newton Bulk - Leach 138 kv line upgrade has been identified as a required upgrade in a prior Facilities Study (OASIS request ). Should the transmission customers in the referenced requests commit to this upgrade, then ETEC may be responsible for financial payments pursuant to Attachment T to Entergy s OATT. If the prior transmission service request (OASIS request ) is withdrawn, then ETEC would be responsible for this upgrade Upgrade Rayburn - Jasper 138 kv transmission line The Rayburn - Jasper 138 kv transmission line overloads for the loss of the Quarry - Crockett 345 kv transmission line. It is required that the Rayburn - Jasper 138 kv transmission line be upgraded from a capacity of 112 MVA to at least 124 MVA Upgrade Huntsville - Wyntex Tap (L558TP91) 138 kv transmission line The Huntsville - Wyntex Tap (L558TP91) 138 kv transmission line overloads for the loss of the Quarry - Grimes 345 kv transmission line. It is required that the Huntsville - Wyntex Tap (L558TP91) 138 kv transmission line be upgraded from a capacity of 143 MVA to at least 149 MVA AEP Affected System Study The Grimes - Crockett 345 kv line is a tie between Entergy and AEP. The impact caused by the proposed project above needs to be evaluated AEP as an Affected System. The customer will need to satisfy the requirements deemed necessary by AEP. 7

8 1.3 Cost Summary The estimated total project cost is $133,430,267 (includes $14,629,508 of AFUDC and $302,173 for work at Crockett to be done by AEP/SWEPCO). This cost does not include Tax Gross Up which may apply. Please note these are 2011 dollars and do not include tax gross-up if and where applicable (Tax Gross Up rate at this time is 24.21%). Should the customer agree to proceed with the project with a preapproved payment plan, the AFUDC amount will be exempted. The ICT has assigned $3,600,348 as Base Case upgrades and $129,829,919, as Supplemental Upgrade based on Attachment T of Entergy s OATT. 1.4 Schedule Summary The requested in-service date is January 1, The duration of work scoped and estimated below is 60 months starting from December 2011, and is expected to be completed by December 31, Safety Requirements Safety is a priority with Entergy. Safety will be designed into substations and lines. The designs will be done with the utmost safety for personnel in mind for construction, operation, and maintenance of the equipment. All employees working directly or indirectly for Entergy shall adhere to all rules and regulations outlined within the Entergy Safety manual. Entergy requires safety to be the highest priority for all projects. All Entergy and Contract employees must follow all applicable safe work procedures. 3. General Assumptions Sufficient time will be allowed in approving the project enabling Entergy to prepare a PEP, and be able to complete the project, as per the schedule described below. Use of the Facilities Study and estimates is not favored to commence an approved project. Assumptions have been made in developing estimates without performing site visits, surveys, and soil borings. During PEP, these tasks will be completed and could have an impact on estimates and schedule. All costs above represent good faith estimates in today s dollars and are based on existing data, and could change considerably after development of detailed PEP. Price escalation for work in future years has not been included. Relay settings and RTU configuration details need to be specified during PEP stage, such as equipment and schemes for pilot protections. 8

9 System changes will be modeled in ASPEN. Relay Impact Analysis will be performed by a settings engineer during PEP stage to identify requirements for relay/ct replacement, and settings revisions at the local and remote stations in the area. For example, affected elements include Z2, Z3, and ground over current settings, and so on. Some obsolete relays may need to be replaced. Communicate the project and protection coordination with nuclear, generation plants, load customers and other interconnected utilities, as appropriate. Comply with PRC-001, PRC-023 and relevant procedures, standards and guidelines, as appropriate. New RTU configurations or revisions will be necessary for stations where new equipment is installed or equipment replacement takes place. For example, there may be a need to map the additional points from a new or different relay. Facility upgrade (new NERC requirements) and N-1 considerations requiring additional work for securing outages are not included in developing this study. Additional funds may be required that is not possible to estimate at this time. 9

10 4. Scope of work NOTE: The scope and estimates are based on a study performed in 2006 and is updated with the latest information available in a limited time. No real estate or other regulatory investigations were conducted to determine availability of site for new substation and new line, and no environmental or ownership issues related to them were investigated. No survey, soil borings or ground analysis was performed. 4.1 New Quarry Substation General Sketch of Proposed Quarry Switching Station Build a three breaker ring bus 345 kv Substation called Quarry Substation with lines cut-in from the existing line between Grimes and Crockett Substation (L119) and to a new line (L831) built from Rivtrin Substation. The section of line between Quarry and Grimes will be renumbered to L832. Assumed configuration is a folded ring bus. 10

11 Assumptions Station orientation allows for direct connection to the 345 kv Lines 2 Independently sourced distribution feeders are available for station service power (cost is not included in this estimate). IPO breakers are options at 345 kv and cost is the same as the CBS breakers No extreme soil conditions exist which would require special foundations. Drilled pier foundation and shallow footings below grade are estimated for use. No environmental or wetlands issues are involved. The site is assumed to be located outside of any floodways/flood plains and is above the 100 year base flood elevation for the area. Since property location information was not included at this time, 3 feet of fill is assumed to be required for site development. Substation will utilize subsurface drainage. All excavated material is assumed unsuitable for re-use. Site size required is 6 acres consisting of wooded area. Site Work Install Qty Item 6 Acre Brush and trees to 6 trunk diameter 6 Acre Brush and trees (Waste Disposal) 1 Each Soil Boring & Study 1 Each Site Surveying 1 Each Environmental Impact 1 Each Permit & License 1 Each Inductive Coordination 1 Each Ground Grid Analysis 1 Each SWMPP Installation Costs and Monitoring 10,000 CYDS Excavate and Grade 5,000 CYDS Stripping of Topsoil 23,000 CYDS Soil Disposal 44,000 CYDS Fill Dirt & Compact 6 Acre Soil Sterilization 2 Acre Seed and Mulching 12,000 Tons Lime Stone Surfacing (Substation Pad + Interior Roads) 1,000 Access Roadway (Outside Substation) 400 Corrugated Metal Pipe Culverts Corrugated Metal Pipe Culverts Corrugated Metal Pipe Culverts Each Catch Basins 2,000 Fence - New 11

12 Foundation Work Install the following foundations: Qty Item 3 Breaker, Dead Tank (Gas) 14 Equip Supt, CCVT 9 Equip Supt, Arrester 5 Equip Supt, Line Trap 4 Bus Supt, High-Elevation - 1 phase 10 Bus Supt, High-Elevation - 3 phase 37 Bus Supt, Low-Elevation - 1 phase 15 Bus Supt, Low-Elevation - 3 phase 12 Switch Supt, Low 3 Dead-end, Full Tension - 2E 1 Control House 20 X Yard Lights 9 Shield Masts 1 Control House 20 X 36 Install the following: Qty Item 23,000 Ground Grid - New 16,000 Conduit & Fitting - New 700 Cable Trench - Pre-cast (adjust for Cast-in-Place) 4 Each Pull Boxes 1 Lot Miscellaneous Material Electrical Work Install the following steel structures: Qty Item kv, Dead-End, Equip Supt, CCVT 9 Equip Supt, Arrester 5 Equip Supt, Line Trap 4 Bus Supt, High-Elevation - 1 phase 10 Bus Supt, High-Elevation - 3 phase 37 Bus Supt, Low-Elevation - 1 phase 15 Bus Supt, Low-Elevation - 3 phase 12 Switch Supt, Low 12 Switch spacer 16 Yard Lights 9 Shield Masts 12

13 Install the following equipment and materials: Qty Item 1 Control House 20 X 36 (including site services and off-loading) 3 Breaker, 362 KV, 3000 AMP, 40 KA, IPO 10 Switch, Vertical Break, 345 KV, 3000 AMP 3 Ground Switch, 345 KV 10 Motor Mechanism, 125 VDC 9 Surge Arrester, 345 KV, Station Class 290 Post Insulator, Porcelain, 345 KV, 7 B.C., 1450 LB 6,600 Rigid Bus (4 and 6 Sch 80 Aluminum EHV) 6,000 Strung Bus (size varies) 4,000 Shield Wire 2 Station Service Equip (50KVA transformer / AC panel/transfer switch) 2 AC Panel Safety Switch (200A) Perform the following: Qty Item 1 Lot Clean Up / Final Close Out 3 Each Breaker Hauling 1 Lot Substation Signage 52 Week Guard Service Relay Quarry substation will be new construction with three (3) standard 362kV high voltage breakers in a ring bus configuration. Each node will have dual primary pilot schemes for the transmission lines conforming to Entergy Standard PM1803. Three (3) breaker control panels conforming to Entergy Standard PM0501, option B, latest revision, will be necessary to provide breaker control functions for the breakers and MOS controls for the breaker disconnect switches. The primary 1 and primary 2 pilot schemes for the Grimes and Crockett lines will be carrier using phase to phase coupling. Therefore, two (2) coupling capacitor voltage transformers purchased according to Entergy standard PN will be installed on these lines ahead of the line traps. The Rivtrin line will use a fiber pilot channel for the primary 1 scheme and carrier pilot channel (single phase coupling) for the primary 2 scheme. Therefore one (1) coupling capacitor voltage transformers purchased according to Entergy standard PN will be installed on this line ahead of the line trap. To provide line polarization potential for the line relaying three (3) CCVTs will be installed at each node of the ring bus. All the CCVTs must be purchased with carrier accessories, since power line carrier will be used for communication purposes. 13

14 Three (3) CCVT junction boxes will be purchased to accept the line potentials of the carrier coupling CCVTs. Three (3) bus potential junction boxes will be purchased to accept the threephase polarization potential of the bus CCVTs. Two (2) stand alone DC panels with appropriately sized breakers will need to be purchased according to Entergy Standard PM One (1) standalone AC panel will be purchased according to Entergy Standard PM AC power to the substation control house and field equipment will be supplied from station service transformers connected to near-by distribution feeders. One (1) Ac transfer switch will be purchased to switch between primary AC power and backup AC power. Two (2) substation battery sets, battery chargers, and maintenance switches will need to be installed. The 125VDC battery sets should be appropriately sized to meet the power requirements of the substation and Entergy Standard PM The chargers must also be appropriately sized to the battery banks and conform to Entergy Standard PM It is assumed that the existing inter-company metering for this line segment is located at the Crocket station and will not required any upgrades or modifications. Relaying for Grimes line Two (2) physically independent pilot schemes are required for the dual primary DCUB/DTT scheme to protect the line. Two (2) dedicated line relay panels conforming to Entergy Standard PM1803, latest revision (option I2), will be necessary. The Ametek Pulsar UPLC will be used for a three-frequency unblock application on each line relay panel for communication purposes. Two (2) CCVTs (one each on A&C phases) with carrier accessories will be needed for this line. The line will also need two (2) 2000A line traps and tuners, one (1) each installed on A&C phases per Entergy Standard PM The controls for the line motoroperated switch will be installed on the primary 1 panel. The primary 2 panel will need to be modified to delete the 311C backup relay, and the line MOS control functions. It is assumed that new carrier frequencies will be assigned to this new line segment. Relaying for AEP/SWEPCO Crockett Line Two (2) physically independent pilot schemes are required for the dual primary DCUB/DTT scheme to protect the line. Two (2) dedicated line relay panels conforming to Entergy Standard PM1803 latest revision (optioni2) will be necessary. The Ametek Pulsar UPLC will be used for a three-frequency unblock 14

15 application on each line relay panel for communication purposes. Two (2) CCVTs (one (1) each on A&C phases) with carrier accessories will be needed for this line. The line will also need two (2) 2000A line traps and tuners one each installed on A&C phases per Entergy Standard PM The controls for the line motoroperated switch will be installed on the primary 1 panel. The primary 2 panel will need to be modified to delete the 311C backup relay and the line MOS control functions. It is assumed that existing carrier frequencies will be reused for this new line segment. Relaying for Rivtrin line Two (2) physically independent pilots are required for the dual primary scheme to protect the line. Two (2) dedicated line relay panels conforming to Entergy Standard PM1803, latest revision (optionc2 for P1 and option I2 for P2), will be necessary. The primary 1 panel will be a digital panel using a SEL-421 as the primary relay to perform line protection with a POTT/DTT scheme, and a 311L to perform DIFF/POTT/DTT over fiber. Controls for a line motor-operated switch will also be located on this panel. The primary 2 line relay panel will use a SEL-421 as the primary relay, and protect the line with a POTT/DTT scheme. Communication will be accomplished via power line carrier through an Ametek UPLC. The controls for the motor-operated line switch will also be located on this panel. The primary 2 panel will need to be modified to delete the 311C backup relay and the line MOS control functions. RTU and Communications A GE D400S RTU will be purchased and used for alarming and control functions. The RTU will also serve as the communications processors for the substation relays. Each relay will be connected to one of the D400S s RS232 ports via SEL-273A cables. This will provide SCADA with alarms and analog values from the relays, and will make time synchronization possible. One (1) cyber security cabinet will be purchased for the housing of the RTU and GPS clock. This cabinet will be equipped with mag locks and a card reader. A SEL-2407 GPS clock will be installed to provide accurate time to the RTU and relays. An antenna must be mounted to the roof of the control house to obtain sufficient signal strength. The SEL-2407 will connect to the D400S directly using coax cable. Fiber will be available to the substation via the transmission line from Rivtrin. Fiber communications will be used for the substation phone and D400S RTU. Relay Settings Quarry switching station is a new 345 kv three-breaker ring bus station providing interconnections to Grimes, to Crockett, and to the Rivtrin 15

16 Substation. Redundant pilot relaying schemes will be applied using Entergy standards for design. Relay settings will be required for each line panel and for the three breaker control panels. Develop settings for Grimes and Crockett each having two (2) dedicated line relay panels with DCUB/DTT scheme conforming to Entergy Standard PM1803 latest revision and Ametek UPLC 3-F Unblock application. Develop settings for Rivtrin with two (2) dedicated line relay panels having SEL421/SEL311C conforming to Entergy Standard PM1803, latest revision (optionc2 for P1 and option I2 for P2). Also, develop settings for carrier settings with AMTEK UPLC. Construction Considerations and Outage Duration Requirements If this project is approved and enters the Transmission Business s (PM&C) process for executing projects, there will be constructability reviews performed during the definition phase. These reviews will try to incorporate any known hazards from a safety perspective, as well as any obstacles that could/would be experienced during the construction and installation process. After receipt of the final design drawings and details for each discipline of work, a determination will be made to either perform a competitive bid process to award the work to an Entergy approved contractor, or, to allow internal Entergy Resources to perform the work. The normal process would be to perform all of the site, foundation, grounding and conduit work with a single source. This is a new substation so all the work will be green field. Outage will be needed when a line L-119 from Grimes to Crockett cutin to Quarry station. Outage will be required for about three weeks long. This outage will be coordinated between Entergy and AEP/SWEPCO due to criticality of the line L-119. Normally outages on 345 kv facilities a 4-5 months advance noticed, with no guarantee that said outage will be granted at the time requested. This poses risk to all schedules. Upon completion of the site and foundation installation including all associated conduits and grounding installations, Steel and Electrical installations as well as Protection and Control installations will commence. For the installation of the proposed components to terminate the Rivtrin 345 kv new transformer does not require an outage and work will be done green field. Upon completion of the proposed additions to the Rivtrin and new Quarry 345 kv ring bus, all preliminary check out and commissioning components that can be made at this juncture will be made, with the exception of the activities that must take place upon final energization. Upon completion of the new Quarry 345 kv facility, final commissioning and checkout will be performed. This will also include end to end checkouts, and remote settings. 16

17 It will require approximately four months completing this project. SWPPP implementation, monitoring, security guard and storage are considered in the estimates. 4.2 Rivtrin Substation General Assumptions Sketch of Proposed Rivtrin with Expansion Station Orientation and location is (as shown in sketch above) north and west of the existing substation and pipelines and six (6) acres is available for substation (this does not include land required for T-line connections). Oil containment is required for the four (4) single-phase autos. No extreme soil conditions exist which would require special foundations. Drilled pier foundation and shallow footings below grade are estimated for use. 17

18 No environmental or wetlands issues are involved. The site is assumed to be located outside of any floodways/flood plains and is above the 100 year base flood elevation for the area. The property northwest of the existing Rivtrin substation slopes down away from the substation. Three (3) feet of fill is assumed to be required for site development. Substation will utilize subsurface drainage. All excavated material is assumed unsuitable for re-use. Site size required is six (6) acres consisting of wooded area. Site Work Install: Qty Item 6 Acre Brush and trees to 6 trunk diameter 6 Acre Brush and trees (Waste Disposal) 1 Each Soil Boring and Study 1 Each Site Surveying 1 Each Environmental Impact 1 Each Permit & License 1 Each Inductive Coordination 1 Each Ground Grid Analysis 1 Each SWMPP Installation Costs and Monitoring 10,000 CYDS Excavate and Grade 5,000 CYDS Stripping of Topsoil 23,000 CYDS Soil Disposal 44,000 CYDS Fill Dirt & Compact 6 Acre Soil Sterilization 2 Acre Seed and Mulching 12,000 Tons Lime Stone Surfacing (Substation Pad + Interior Roads) 200 Access Roadway (Outside Substation) 400 Corrugated Metal Pipe Culverts Corrugated Metal Pipe Culverts Corrugated Metal Pipe Culverts Each Catch Basins 2,000 Fence - New Foundation Work Install the following foundations: Qty Item 4 345/138 kv 1 ph 200MVA autotransformer (Gas) 4 Containment around autotransformers 3 Concrete Fire Walls between transformers 18

19 3 Equip Supt, 345 kv CCVT 3 Equip Supt, 345 kv Arrester 1 Equip Supt, 345 kv Line Trap 6 Bus Supt, 345 kv,high-elevation - 1 phase 1 Bus Supt, 345 kv,low-elevation - 3 phase kv Dead-end, Full Tension - 2E kv Dead-end, 1 phase for Auto Area 1 Switch Supt, 345 kv, Low 6 Bus Supt, 345 kv Low-Elevation - 1 phase 2 Bus Supt, 345 kv High-Elevation - 3 phase kv Dead-end, H- frame? kv Equip Supt, CCVT kv Equip Supt, SSVT kv Equip Supt, Arrester kv Bus Supt, Low-Elevation - 1 phase kv Bus Supt, High-Elevation - 1 phase kv Bus Supt, High-Elevation - 3 phase kv Switch Supt, Low (1 w/bki brackets) kv Switch Supt, High kv Auto area structure around Autos 10 Control House 20 X Yard Lights 6 Shield Masts Install the following: Qty Item 25,000 Ground Grid - New 18,000 Conduit & Fitting - New 900 Cable Trench - Pre-cast (adjust for Cast-in-Place) 4 Each Pull Boxes 1 Lot Miscellaneous Material Electrical Work Install the following steel structures Qty Item 3 Equip Supt, 345 kv CCVT 3 Equip Supt, 345 kv Arrester 1 Equip Supt, 345 kv Line Trap 6 Bus Supt, 345 kv,high-elevation - 1 phase 1 Bus Supt, 345 kv,low-elevation - 3 phase kv Dead-end, Full Tension - 2E kv Dead-end, 1 phase for Auto Area 1 Switch Supt, 345 kv, Low 2 Bus Supt, 345 kv Low-Elevation - 1 phase 6 Bus Supt, 345 kv High-Elevation - 3 phase kv Dead-end, H- frame? 19

20 kv Equip Supt, CCVT kv Equip Supt, SSVT kv Equip Supt, Arrester kv Bus Supt, Low-Elevation - 1 phase kv Bus Supt, High-Elevation - 1 phase kv Switch Supt, Low (1 w/bki brackets) kv Switch Supt, High kv auto area structure around autos kV tertiary bus structures near autos 18 Yard Lights 6 Shield Masts kv Bus Supt, High-Elevation - 3 phase Install the following equipment and materials: Qty Item 4 345/138 kv 1 phase 200MVA autotransformer (gas) 1 Switch, Vertical Break, 345 KV, 3000A, 1 Ground Switch, 345 KV 1 Motor Mechanism for 345 kv switch, 125 VDC 2 SSVT, /120 including AC Panel and transfer switch) 2 AC Panel Safety Switch (200A) 1 Control House 20 X 36 (including Site services and off loading) 8 Breaker, 145 KV, 3000 AMP, 40 KA, IPO 17 Switch, Vertical Break, 138 KV, 3000 AMP 5 Ground Switch, 138 KV 17 Motor Mechanism for 138 kv switch, 125 VDC 3 Surge Arrester, 345 KV, Station Class 18 Surge Arrester, 138 KV, Station Class, Polymer 33 Post Insulator, Porcelain, 345 KV, 7 B.C., 1400 LB 175 Post Insulator, Porcelain, 138 KV, STD., 1450 LB 60 Post Insulator, Polymer, 138 KV 30 Post Insulator, Polymer, 13.8 KV, (TERTIARY) 9 Suspension Insulator, Polymer, 138 KV kv Rigid Bus (4 and 6 Sch 80 Aluminum EHV) kv Strung Bus (Size Varies) 4, kv Rigid Bus (4 and 6 Sch 40 Aluminum) 3, kv Strung Bus (Size Varies) 1,200 Shield Wire Perform the following: Qty Item 1 Lot Clean Up / Final Close Out 4 Each Autotransformer Hauling, Testing and Processing 8 Each Breaker Hauling 1 Lot Substation Signage 52 Week Guard Service 20

21 Perform the following at the existing Rivtrin Box steel: Coordinate with T-Lines the relocation of Lines L-509, L-91/L-558 and L-487 to the new expansion area. Remove (2) 1200A switches and relocate 1 on outer bay (where L-487 was previously located) for connection to the 134kV/34.5kV transformer #2 circuit switcher. Remove and haul 138 kv breaker 6865 to facilitate relocated switch. Remove 134kV, 1200A horizontally mounted vertical break switch and stand for transformer #2. Install bus (wrapped around to the west side of the box steel structures included above) from transformer #2 circuit switcher to relocated switch on west side of box steel. Reconfigure bus in box steel to make it a completed 5 element ring bus with the connection to the new expansion where L-509 was previously located. Relays General The construction at Rivtrin Substation will include the addition of eight (8) 138 kv breakers, one (1) autotransformer, and the relocation of three (3) line bays. Three (3) breaker control panels conforming to Entergy Standard PM0501, option B, latest revision, will be necessary to provide breaker control functions for the tie breakers. Two (2) autotransformer differential panels conforming to Entergy Standard PM3507, option B, latest revision, will be necessary to provide transformer protection. One (1) panel will cover the differential zone around the transformer only, and the other panel will cover the differential zone around the transformer and also the high side breakers. One (1) bus differential panel conforming to Entergy Standard PM0602, option B, latest revision, will be necessary for additional autotransformer protection of the 138 kv bus. 21

22 One (1) bus differential panel conforming to Entergy Standard PM0602, option B, latest revision, will be necessary to protect the new bus segment between existing breakers 6885 and 6465 on the existing 138 kv side of the station. One (1) line/breaker control panel with no pilot conforming to Entergy Standard PM1803, option Q will be installed for additional protection of the 138 kv bus section on the low-side of the transformer. The panel uses a SEL- 421 for primary protection and breaker control functions, and a SEL-311C for backup protection to the autotransformer. Two (2) dedicated line/breaker control panels conforming to Entergy Standard PM1803 latest revision (option B2) will be necessary to protect the line section that jumpers the new 345/138 kv addition to the existing 138 kv bus #2. These panels will be digital panels using a SEL-421 as the primary relay to perform line protection with a POTT/DTT scheme and a 311L to perform DIFF/POTT/DTT over fiber. One (1) will be placed in the new control house and the other will be placed in the old control house. Four (4) high impedance bus differential panels conforming to Entergy Standard PM0602, option B, latest revision, will be necessary for protection of the two (2) new 138 kv buses. Each bus will use two (2) bus differential panels for redundant protection. Eight (8) coupling capacitor voltage transformers purchased according to Entergy standard PN will be necessary to provide line potential for each new 138 kv line. Three (3) of the CCVTS will be 345 kv and five (5) of them will be 138 kv. The primary 2 pilot scheme for the Quarry line will be carrier using phase to phase coupling, so one CCVT will be installed on this line ahead of the line trap. Two (2) CCVTs will be installed behind the trap to complete the three-phase line polarizing potential. All the CCVTs must be purchased with carrier accessories since power line carrier will be used for communication purposes. Six (6) CCVT junction boxes will be purchased to accept the line potentials of the carrier coupling CCVTs. Six (6) 138 kv CCVTs will be necessary to provide three-phase polarizing potential for each new 138 kv bus. Three (3) CCVTs will be placed on each bus and must conform to Entergy Standard PM Two (2) bus potential junction boxes will be purchased to accept the threephase polarization potential of the bus CCVTs. Two (2) indoor bus potential distribution boxes will be purchased to distribute the three-phase polarization potential of each bus to the necessary equipment. 22

23 One (1) automatic bus potential transfer panel to enable switching from the potential of one (1) bus to the potential of the other bus to ensure that polarizing bus potential is always available. One (1) standalone DC panel with appropriately sized breakers will need to be purchased according to Entergy Standard PM One (1) standalone AC panel will be purchased according to Entergy Standard PM One (1) substation battery set, battery charger, and maintenance switch will need to be installed. The 125 VDC battery set should be appropriately sized to meet the power requirements of the substation and Entergy Standard PM The charger must also be appropriately sized to the battery bank and conform to Entergy Standard PM AC power to the substation s new control house and field equipment will be supplied from an SSVT. One (1) AC transfer switch will be purchased to switch between primary AC power and backup AC power. The line relaying for L-91/L-558 will be disabled and the corresponding panels will be removed from the existing control house. The panel containing the breaker failure functions for breaker 6885 will remain in the control house to continue providing breaker control. The line relaying for L-487 will be disabled and the corresponding panels will be removed from the existing control house. The panel containing breaker control functions for breaker 6465 will remain in the control house to continue to provide breaker control for this breaker. Any line relaying on this panel will be disabled. The line relaying for L-509 will be disabled and the corresponding panel will be removed from the existing control house. Breaker 6865 will be removed from the substation and all corresponding control panels will be removed from the existing control house. Relaying for Quarry Line Two (2) physically independent pilots are required for the dual primary scheme to protect the line. Two (2) dedicated line relay panels conforming to Entergy Standard PM1803 latest revision (option C2 for P1 and option I2 for P2) will be necessary. The primary 1 panel will be a digital panel using a SEL-421 as the primary relay to perform line protection with a POTT/DTT scheme and a 311L to perform DIFF/POTT/DTT over fiber. Controls for a line motor-operated switch will also be located on this panel. The primary 2 line relay panel will use a SEL-421 as the primary relay and protect the line with a 23

24 POTT/DTT scheme. Communication will be accomplished via power line carrier through an Ametek UPLC. The primary 2 panel will need to be modified to delete the 311C backup relay and the line MOS control functions. One (1) 2000A line trap and tuner will be purchased according to Entergy Standard PM for this line. Relaying for Pee Dee Line One (1) line/breaker control panel conforming to Entergy Standard PM1803 latest revision (option H2) will be necessary. This panel uses a SEL-421 and 311C will be used to in a POTT/DTT scheme to protect the line. The Ametek Pulsar UPLC will be used for a three-frequency unblock application on the panel for communication purposes. One (1) CCVT with carrier accessories will be needed for this line. The line will also need one (1) 2000A line trap and tuner per Entergy Standard PM Relaying for Huntsville Line One (1) line/breaker control panel conforming to Entergy Standard PM1803, latest revision (option H2), will be necessary. This panel uses a SEL-421 and 311C will be used to in a POTT/DTT scheme to protect the line. The Ametek Pulsar UPLC will be used for a three-frequency unblock application on the panel for communication purposes. One (1) CCVT with carrier accessories will be needed for this line. The line will also need one (1) 2000A line trap and tuner per Entergy Standard PM Relaying for Lewis Creek line One (1) line/breaker control panel conforming to Entergy Standard PM1803, latest revision (option H2), will be necessary. This panel uses a SEL-421 and 311C will be used to in a POTT/DTT scheme to protect the line. The Ametek Pulsar UPLC will be used for a three-frequency unblock application on the panel for communication purposes. One (1) CCVT with carrier accessories will be needed for this line. The line will also need one (1) 2000A line trap and tuner per Entergy Standard PM RTU and Communication A GE D400S RTU will be purchased and used for alarming and control functions of the new equipment being added to the new control house. The RTU will also serve as the communications processors for the substation relays in the new control house. Each relay will be connected to one of the D400S s RS232 ports via SEL-273A cables. This will provide SCADA with alarms and analog values from the relays and will make time synchronization possible. 24

25 One (1) cyber security cabinet will be purchased for the housing of the RTU and GPS clock. This cabinet will be equipped with mag locks and a card reader. A SEL-2407 GPS clock will be installed to provide accurate time to the RTU and relays. An antenna must be mounted to the roof of the control house to obtain sufficient signal strength. The SEL-2407 will connect to the D400S directly using coax cable. Fiber will be available to the substation via the transmission line from Quarry. Fiber communications will be used for the substation phone and D400S RTU. Relay Settings and RTU Configuration The Rivtrin 345 kv line, which connects directly into an autotransformer, will require redundant pilot relaying schemes of Entergy standard design. Protection and control settings will be required. Develop relay settings for three (3) breaker control panels conforming to Entergy Standard PM0501, option B, latest revision, to provide breaker control functions for the tie breakers. The Rivtrin 345 kv/138 kv autotransformer will be connected into a new section of the Rivtrin substation that consists of a five-breaker ring bus. The Rivtrin autotransformer will require development of settings for both primary and secondary protection schemes. Develop relay settings for two (2) autotransformer differential panels conforming to Entergy Standard PM3507, option B. The new section of Rivtrin will be connected to the existing Rivtrin facilities by a new Line/Bus section. This section of bus will require redundant bus differential relaying and the required settings for each per Entergy standard PM0602 Option B, latest revision. Develop settings for one (1) line/breaker control panel with no pilot conforming to Entergy Standard PM1803, option Q, for the protection of 138 kv bus section on the low-side of the transformer with SEL421/SEL311C. Develop settings for two (2) dedicated line/breaker control panels conforming to Entergy Standard PM1803, latest revision (option B2), will be necessary to protect the line section that jumpers the new 345/138 kv addition to the existing 138 kv bus #2 with SEL421/SEL311L. Develop settings for four (4) high impedance bus differential panels conforming to Entergy Standard PM0602, option B, latest revision, for protection of the two (2) new 138 kv buses. 25

26 Develop settings for Quarry line with two (2) dedicated line relay panels conforming to Entergy Standard PM1803, latest revision (option C2 for P1 and option I2 for P2), with SEL421 (POTT/DTT)/SEL311L (DIFF/POTT/DTT). Also develop settings for power line carrier equipment with Ametek UPLC. Develop settings for Pee Dee line with (1) line/breaker control panel conforming to Entergy Standard PM1803, latest revision (option H2), and Ametek UPLC. Develop settings for Huntsville line with one (1) line/breaker control panel conforming to Entergy Standard PM1803, latest revision (option H2), and Ametek UPLC. Develop settings for Lewis Creek with one (1) line/breaker control panel conforming to Entergy Standard PM1803, latest revision (option H2), and Ametek UPLC. Develop necessary RTU configurations. The existing section of Rivtrin will incorporate a replacement breaker and the removal of a breaker. Settings revisions will be required for the protection of the two load transformers. The breaker control relay settings will require settings development or revision for the two (2) breakers associated with the line/bus connection to the new section of Rivtrin. Construction Considerations and Outage Duration Requirements If this project is approved and enters the Transmission Business s (PM&C) process for executing projects, there will be constructability reviews performed during the definition phase. These reviews will try to incorporate any known hazards from a safety perspective, as well as any obstacles that could/would be experienced during the construction and installation process. After receipt of the final design drawings and details for each discipline of work, a determination will be made to either perform a competitive bid process to award the work to an Entergy approved contractor, or to allow internal Entergy Resources to perform the work. The normal process would be to perform all of the site, foundation, grounding and conduit work with a single source. Dependant on the final design a determination will be made to address any system outages that may be required to perform the installations of any proposed foundations. Outages will be carefully coordinated removal of breaker and associated components into existing 138 kv facilities, relocation of line L-509 to PeeDee, line L-91/L-558 to Huntsville and line L-487 to Lewis Creek stations. Outages will be also carefully coordinated to connect new 138 kv facilities with existing facility at Rivtrin station. Efforts will be made to utilize low profile excavation equipment as part of the installation process for any foundations that will be under, near, adjacent too, or in close proximity of energized conductors that could be determined to be a safety risk. In the instances that this is not attainable, outage will be required. Normally, outages on 138 kv facilities are 26

27 two (2) to three (3) months advance noticed, with no guarantee that said outage will be granted at the time requested. This poses risk to all schedules. Upon completion of the site and foundation installation, including all associated conduits and grounding installations, Steel and Electrical installations as well as Protection and Control installations will commence. For the installation of the proposed transformer to terminate the New Quarry 345 kv ring bus, no outage is required. Upon completion of the proposed additions to the Rivtrin 138 kv and 345/138 kv transformer, all preliminary check out and commissioning will be made, with the exception of the activities that must take place upon final energization. Upon completion of the new proposed Rivtrin 138 kv facility, final commissioning and checkout will be performed. This will also include end-to-end checkouts, and remote settings. It will require approximately four (4) months completing this project. SWPPP implementation, monitoring, security guard and storage are considered in the estimates. 27

28 4.3 Grimes Substation (relating to line cut-in) Site Work None required. Foundation Work None required. Electrical Work None required. Relays General A new 345 KV substation, Quarry Switching Station, will be constructed and connected in the line segment between Grimes and Crockett (L-119). As a result, the existing line protection for L-119 at Grimes will be upgraded to match the relaying schemes being installed at Quarry Switching Station. The breaker control panels for breakers and will be reused. The line traps will be reused, but will need new tuning packs for the new carrier frequencies assigned to this line segment. New line tuners will be purchased. It is assumed that the existing AC panel, DC panel, RTU, and communication equipment have sufficient spare capacity and will not need to be upgraded. Grimes to Quarry Transmission Line relaying Two (2) physically independent pilot schemes are required for the dual primary DCUB/DTT scheme to protect the line. Two (2) dedicated line relay panels conforming to Entergy Standard PM1803, latest revision (option I2), will be necessary. The Ametek Pulsar UPLC will be used for a three-frequency unblock application on each line relay panel for communication purposes. It is assumed the existing carrier coupling line CCVTs (one each on A&C phases) can be reused. The existing line traps will be retuned for the new carrier frequencies and new line tuners will be purchased. The controls for the line motor-operated switch will be installed on the primary 1 panel. The primary 2 panel will need to be modified to delete the 311C backup relay and the line MOS control functions. 28

29 Relay Settings and RTU configuration Develop settings for Quarry line with two (2) physically independent dual primary pilot DCUB/DTT scheme per Entergy Standard PM1803, latest revision (option I2). Also develop settings for power line carrier with Ametek 3-F UPLC. Develop necessary RTU configurations. Construction methodology and outage requirements If this project is approved and enters the Transmission Business s (PM&C) process for executing projects, there will be constructability reviews performed during the definition phase. These reviews will try to incorporate any known hazards from a safety perspective, as well as any obstacles that could/would be experienced during the construction and installation process. After receipt of the final design drawings and details for relay work, a determination will be made to either perform a competitive bid process to award the work to an Entergy approved contractor, or, to allow internal Entergy Resources to perform the work. Relay work consist of breaker control panels, new tuning packs for carrier frequencies and relay work. 29

30 4.4 Crockett Substation (Owned by AEP/SWEPCO) General A new 345 KV substation, Quarry Switching Station, will be constructed and connected in the line segment between Grimes and Crockett (L-119). As a result the existing line protection for L-119 at Crockett will be upgraded to match the relaying schemes being installed at Quarry Switching Station. The breaker control panels for breakers will be reused. The existing line traps, line tuners and carrier coupling CCVTs will be reused, as it is assumed the new carrier frequencies for this line segment will not change. It is assumed that the existing AC panel, DC panel, RTU, and communication equipment have sufficient spare capacity and will not need to be upgraded. Assumed Entergy will incur the cost of the relay upgrade at the Crockett Substation. Assumed 4,000 of new cable (20 cables at 200 each) will be required from new line and breaker panels to the new equipment (CVTs, line traps, breaker, motor-operated switches, etc.) in the yard and control house for L832. AEP/SWEPCO would be responsible for the cost and the work to be done. Crockett to Quarry Transmission Line relaying Two (2) physically independent pilot schemes are required for the dual primary DCUB/DTT scheme to protect the line. Two (2) dedicated line relay panels conforming to Entergy Standard PM1803, latest revision (option I2), will be necessary. The Ametek Pulsar UPLC will be used for a three-frequency unblock application on each line relay panel for communication purposes. It is assumed the existing carrier coupling line CCVTs (one (1) each on A&C phases) can be reused along with the existing line traps and line. The controls for the line motoroperated switch will be installed on the primary 1 panel. The primary 2 panel will need to be modified to delete the 311C backup relay and the line MOS control functions. Relay Settings and RTU configuration Develop settings for Quarry line with Two (2) physically independent dual primary pilot DCUB/DTT scheme per Entergy Standard PM1803 latest revision (option I2). Also develop settings for power line carrier with Ametek 3-F UPLC. Develop necessary RTU configurations. 30

31 Construction methodology and outage requirements AEP/SWEPCO will handle all construction and relay work as identified in this document with coordination with Entergy. Due to criticality of the 345 kv line, L- 119 outage will be coordinated with them. 4.5 Pee Dee Substation Assumptions There is room in the existing cable trench for the additional conduits. Site Work None Foundation Work Install the following foundations Qty Item kv Equip Supt, CCVT/ Line Trap Combo foundation 2 Ground grid pigtails to above structure and associated equipment 1 Pull box for conduit installation 250 Conduit from equipment to pull box and cable trench Electrical Work Install the following steel structures and equipment Qty Item 1 Equip Supt, 138 kv, 2000A CCVT/Line Trap Combo kv, CCVT kv, 2000A Line Trap on CCVT Relays All line relaying associated with L-509 and breaker control functions for breaker will be removed from the substation. One (1) line/breaker control panel conforming to Entergy Standard PM1803, latest revision (option H2), will be necessary. This panel uses a SEL-421 and 311C will be used to in a POTT/DTT scheme to protect the line. The Ametek Pulsar UPLC will be used for a three-frequency unblock application on the panel for communication purposes. This panel will also perform breaker failure functions for breaker

32 One (1) 2000A line trap and tuner per Entergy Standard PM will be necessary to aide power line carrier communications. One (1) CCVT with carrier accessories will be purchased according to Entergy Standard PM020201, and installed ahead of the line trap on the line. Relay Settings and RTU configuration Develop settings for Rivtrin line with one (1) line/breaker control panel (BKR 16130) having SEL421/SEL311C POTT/DTT scheme per Entergy Standard PM1803, latest revision (option H2). Also, develop settings for power line carrier with Ametek 3-F UPLC. Develop necessary RTU configurations. Construction methodology and outage requirements If this project is approved and enters the Transmission Business s (PM&C) process for executing projects, there will be constructability reviews performed during the definition phase. These reviews will try to incorporate any known hazards from a safety perspective, as well as any obstacles that could/would be experienced during the construction and installation process. After receipt of the final design drawings and details for each discipline of work, a determination will be made to either perform a competitive bid process to award the work to an Entergy-approved contractor, or to allow internal Entergy Resources to perform the work. The normal process would be to perform all of the site, foundation, grounding and conduit work with a single source. Dependant on the final design, a determination will be made to address any system outages that may be required to perform the installations of any proposed foundations. Efforts will be made to utilize low profile excavation equipment as part of the installation process for any foundations that will be under, near, adjacent too, or in close proximity of energized conductors that could be determined to be a safety risk. In the instances that this is not attainable, outage will be required. Normally outages on 138 kv facilities are two (2) to three (3) months advance noticed, with no guarantee that said outage will be granted at the time requested. This poses risk to all schedules. Upon completion of the foundation installation, including all associated conduits and grounding installations, Steel and Electrical installations for line trap and tuner, and CCVT, as well as Protection and Control installations, will commence. Upon completion of the new proposed relaying at PeeDee 138 kv facility, final commissioning and checkout will be performed. This will also include end-to-end checkouts, and remote settings for Pee Dee, Huntsville and Lewis Creek. It will require two (2) weeks outage on L-509 and will require approximately two (2) to three (3) weeks for completing this project. 32

33 4.6 Lewis Creek Assumptions There is room in the existing cable trench for the additional conduits. Site Work None. Foundation Work Install the following foundations: Qty Item kv Equip Supt, CCVT/ Line Trap Combo foundation 2 Ground grid pigtails to above structure and associated equipment 1 Pull box for conduit installation 250 Conduit from equipment to pull box and cable trench Electrical Work Install the following steel structures and equipment: Qty Item 1 Equip Supt, 138 kv, 2000A CCVT/Line Trap Combo kv, CCVT kv, 2000A Line Trap on CCVT Relays All line relaying associated with L- and breaker control for breaker 1625 will be removed from the control house. One (1) line/breaker control panel conforming to Entergy Standard PM1803, latest revision (option H2), will be necessary. This panel uses a SEL-421, and 311C will be used to in a POTT/DTT scheme to protect the line. The Ametek Pulsar UPLC will be used for a three-frequency unblock application on the panel for communication purposes. Breaker control functions for breaker 1625 will also be handled by this panel. One (1) 2000A line trap and tuner per Entergy Standard PM will be necessary to aide power line carrier communications. One (1) CCVT with carrier accessories will be purchased according to Entergy Standard PM and install ahead of the line trap on the line. 33

34 Relay Settings and RTU configuration Develop settings for Rivtrin line with one (1) line/breaker control panel (BKR 1625) having SEL421/SEL311C POTT/DTT scheme per Entergy Standard PM1803, latest revision (option H2). Also, develop settings for power line carrier with Ametek 3-F UPLC. Develop necessary RTU configurations. Construction methodology and outage requirements If this project is approved and enters the Transmission Business s (PM&C) process for executing projects, there will be constructability reviews performed during the definition phase. These reviews will try to incorporate any known hazards from a safety perspective, as well as any obstacles that could/would be experienced during the construction and installation process. After receipt of the final design drawings and details for each discipline of work, a determination will be made to either perform a competitive bid process to award the work to an Entergy-approved contractor, or to allow internal Entergy Resources to perform the work. The normal process would be to perform all of the site, foundation, grounding and conduit work with a single source. Dependant on the final design a determination will be made to address any system outages that may be required to perform the installations of any proposed foundations. Efforts will be made to utilize low profile excavation equipment as part of the installation process for any foundations that will be under, near, adjacent too, or in close proximity of energized conductors that could be determined to be a safety risk. In the instances that this is not attainable, outage will be required. Normally outages on 138 kv facilities are two (2) to three (3) months advance noticed, with no guarantee that said outage will be granted at the time requested. This poses risk to all schedules. Upon completion of the foundation installation including all associated conduits and grounding installations, Steel and Electrical installations for line trap and tuner and CCVT as well as Protection and Control installations will commence. Upon completion of the new proposed relaying at Lewis Creek 138 kv facility, final commissioning and checkout will be performed. This will also include end to end checkouts, and remote settings for Pee Dee, Huntsville and Lewis Creek. It will require two (2) weeks outage on L-487 and will require approximately a two (2) to three (3) weeks for completing this project. 34

35 4.7 Huntsville Assumptions There is room in the existing cable trench for the additional conduits. Site Work None. Foundation Work Install the following foundations: Qty Item kv Equip Supt, CCVT/ Line Trap Combo foundation 2 ground grid pigtails to above structure and associated equipment 1 pull box for conduit installation 250 Conduit from equipment to pull box and cable trench Electrical Work Install the following steel structures and equipment: Qty Item 1 Equip Supt, 138 kv, 2000A CCVT/Line Trap Combo kv, CCVT kv, 2000A Line Trap on CCVT Relays All line relaying associated with L-91 and breaker control for breaker will be removed from the control house. One (1) line/breaker control panel conforming to Entergy Standard PM1803 latest revision (option H2) will be necessary. This panel uses a SEL-421 and 311C will be used to in a POTT/DTT scheme to protect the line. The Ametek Pulsar UPLC will be used for a three-frequency unblock application on the panel for communication purposes. One (1) 2000A line trap and tuner per Entergy Standard PM will be necessary to aide power line carrier communications. One (1) CCVT with carrier accessories will be purchased according to Entergy Standard PM and install ahead of the line trap on the line. 35

36 Relay Settings and RTU configuration Develop settings for Rivtrin line with one (1) line/breaker control panel having SEL421/SEL311C (BKR 16130) POTT/DTT scheme per Entergy Standard PM1803 latest revision (option H2). Also develop settings for power line carrier with Ametek 3-F UPLC. Develop necessary RTU configurations. Construction methodology and outage requirements If this project is approved and enters the Transmission Business s (PM&C) process for executing projects, there will be constructability reviews performed during the definition phase. These reviews will try to incorporate any known hazards from a safety perspective, as well as any obstacles that could/would be experienced during the construction and installation process. After receipt of the final design drawings and details for each discipline of work, a determination will be made to either perform a competitive bid process to award the work to an Entergy approved contractor, or, to allow internal Entergy Resources to perform the work. The normal process would be to perform all of the site, foundation, grounding and conduit work with a single source. Dependant on the final design a determination will be made to address any system outages that may be required to perform the installations of any proposed foundations. Efforts will be made to utilize low profile excavation equipment as part of the installation process for any foundations that will be under, near, adjacent too, or in close proximity of energized conductors that could be determined to be a safety risk. In the instances that this is not attainable, outage will be required. Normally outages on 138 kv facilities are two (2) to three (3) months advance noticed, with no guarantee that said outage will be granted at the time requested. This poses risk to all schedules. Upon completion of the foundation installation including all associated conduits and grounding installations, Steel and Electrical installations for line trap and tuner and CCVT as well as Protection and Control installations will commence. Upon completion of the new proposed relaying at Huntsville 138 kv facility, final commissioning and checkout will be performed. This will also include end to end checkouts, and remote settings for Pee Dee, Huntsville and Lewis Creek. It will require two weeks outage on L-91 and will require approximately two (2) to three (3) weeks for completing this project. 36

37 4.8 New 345 kv line L831 between Rivtrin and new Quarry SS General L-831 Quarry to Rivtrin Build New 345 kv Transmission Line from New Substation (Quarry) to existing Rivtrin Substation approximately 9.4 miles long. It is assumed that the 345 kv Line 831 will be built parallel to existing Line 509. Geotechnical Report (Soil Borings) This estimate was performed without the benefit of geotechnical boring data. In order to complete a detailed design, approximately nine (9) soil borings will be required along with their associated Geotechnical reports including the boring logs and the laboratory data. Survey and Plan & Profile Drawings A topographical survey of the T-line alignment will be required. A LIDAR survey data has already been collected on the assumed line route and preliminary Digital Terrain Model data and Mosaic images were provided in conjunction with a previously proposed project. Therefore, if the assumed route is chosen, the estimated cost for topographical surveying could be less than the value quoted on the estimating sheet. Drafting services will be required to complete the Plan & Profile drawings and Phasing diagrams. 37