FACILITIES STUDY TRANSMISSION SERVICE REQUESTS OASIS

Transcription

1 TRANSMISSION / DISTRIBUTION PROJECTS COMPANY:EGSI -LA CUSTOMER: NRG FACILITIES STUDY EJO # F4PPGS0411 TRANSMISSION SERVICE REQUESTS OASIS Revision: 0 Issue Revised Project Rev Description of Revision Date By Manager Bob Kevin 0 04/02/08 Compiled for submission to ICT Perrone Wright 1 04/02/08 ICT Classified Upgrades JDL JH Page 1 of 29

2 EXECUTIVE SUMMARY... 4 SAFETY AWARENESS SCOPE DETAILS COSTS SCHEDULE ATTACHMENTS...25 Page 2 of 29

3 Table of Acronyms A ACSR ACSS ADEQ AEPW AFUDC ANO ATC CLECO CSWS EES EHV ICT kv MCM MDEA MEP MPS MVA MW NPDES NOI OASIS OATT OH OG&E POD POR SOC SHPO SHV SW SWEPCO TGU TOC Amps Aluminum Conductor Steel Reinforced Aluminum Conductor Steel Supported Arkansas Department of Environmental Quality American Electric Power West Allowance for Funds Used During Construction Arkansas Nuclear One Available Transfer Capability Central Louisiana Electric Company Central & Southwest Control Area Entergy Control Area Extra-High Voltage Independent Coordinator of Transmission Kilo-Volt (M) Thousand Circular Mils Mississippi Delta Energy Agency Mississippi Electric Power Missouri Public Service Mega-Volt Amp Mega-Watt National Pollution Discharge Elimination System Notice of Intent Online Access and Same-time Information System Open Access Transmission Tariff Overhead Oklahoma Gas & Electric Point of Delivery Point of Receipt System Operations Center Arkansas State Historic Preservation Office Super High Voltage Switch Station Southwest Electric Power Company Tax Gross Up Transmission Operations Center

4 EXECUTIVE SUMMARY Entergy Transmission Facilities Study OASIS Request Number Transfer from Tennessee Valley Authority to Louisiana Generating LLC The purpose of this Facilities Study is to determine the availability of transfer capability across Entergy s transmission system from Tennessee Valley Authority (TVA) to Louisiana Generating LLC (LAGN), to evaluate the NRG Power Marketing request for 500MW of yearly network transmission service. The time period for this transfer is from 6/1/2008 until 6/1/2014. The direction of the transaction is TVA to LAGN. This study was performed on the latest available June August 2009 monthly cases, summer peak cases and winter peak cases, using PSS/E and MUST software by Power Technologies Incorporated (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. Scope Summary The Facilities Study has identified some transmission constraints. The constraints can be addressed in the following manner: 1. Upgrade the line equipment at the Bogalusa 230kV substation. The Bogalusa-Adams Creek 230 kv transmission line B overloads for the loss of the Bogalusa-Adams Creek 230 kv transmission line A. The Bogalusa-Adams Creek 230 kv transmission line B needs to have a capacity of 874 MVA or greater on all components. The line conductor has a rated capacity of 880 MVA, but the Bogalusa 230 kv breaker #S2520 is rated at 1600A or 637MVA. The breaker and its associated switches need to be upgraded to 3000A. 2. Upgrade the line equipment at the Ray Braswell 500kV and Baxter Wilson 500kV substations. The Ray Braswell-Baxter Wilson 500kV transmission line overloads for the loss of the Grand Gulf-Franklin 500kV transmission line. The Ray Braswell-Baxter Wilson 500kV transmission line needs to have a capacity of 2138MVA or greater on all components. The line conductor has a rated capacity of 2884MVA, but the Ray Braswell 500kV breakers #J4928 and #J4920 and switches #J4919, #J4921, #J4927, and #J4929 and the Baxter Wilson 500kV breaker #J2230 and switches #J2228, #J2229, #J2232, #J2234, #J2249, and #K2283 are rated at 2000A or 1732MVA. The breakers and switches need to be upgraded to 3000A. Page 4 of 29

5 This upgrade has been included in previous facility studies (OASIS request numbers , , , , ). If a previous facility study request and the proposed equipment upgrades are confirmed, the customer would not have to fund this upgrade. Re-dispatch of LAGN and the Transmission Provider resources were reviewed and considered. 3. Upgrade the Hernando-Coldwater-Senatobia 115kV transmission line. The Hernando-Coldwater-Senatobia 115kV transmission line overloads for the loss of the following elements. Limiting Element Contingency Element Hernando-Coldwater 115kV Coldwater-Senatobia 115kV Freeport-Twinkletown-Robinsonville- Tunica 230kV Hernando-Coldwater 115kV Batesville-Moon Lake 230kV Coldwater-Senatobia 115kV Hernando-Coldwater 115kV Moon Lake-Ritchie-Tunica 230kV Hernando-Coldwater 115kV Fancy Point-Riverbend 230kV Hernando-Coldwater 115kV Fancy Point 500/230kV auto #1 Hernando-Coldwater 115kV Desoto-Horn Lake 115kV Hernando-Coldwater 115kV McAdams-Attala 500kV Hernando-Coldwater 115kV Batesville-Como-Crenshaw-Tunica 115kV Hernando-Coldwater 115kV Desoto-Walls-Banks (SMEPA) 115kV Hernando-Coldwater 115kV Gerald Andrus-Indianola 230kV Hernando-Coldwater 115kV Baxter Wilson-Ray Braswell 500kV Hernando-Coldwater 115kV McAdams 500/230kV auto #1 Hernando-Coldwater 115kV Baxter Wilson-Perryville 500kV The following line sections must be upgraded to the specified capacity. Hernando-Coldwater 115kV transmission line must be upgraded from a capacity of 108MVA to at least 131MVA. Coldwater-Senatobia 115kV transmission line must be upgraded from a capacity of 108MVA to at least 118MVA. 4. Energize the Horn Lake 230/161kV autotransformer & upgrade the Horn Lake- Allen (TVA) 161kV transmission line. The Horn Lake 230/115kV autotransformer overloads for the loss of either the Getwell-Horn Lake 230kV transmission line or the Getwell 230/115kV Page 5 of 29

6 autotransformer. The Horn Lake-Allen (TVA) 161kV transmission line overloads for the loss of the Horn Lake-Freeport 230kV transmission line. The Horn Lake 230/115kV autotransformer has a rated capacity of 392MVA but a capacity of at least 422MVA is required. The Horn Lake-Allen (TVA) 161kV transmission line has a rated capacity of 226MVA but a capacity of at least 240MVA is required. The Horn Lake substation has a 230/161kV autotransformer installed and it is available for service. The 2008 ICT Base Plan and Entergy s Transmission Construction Plan has proposed to energize the Horn Lake 230/161kV autotransformer and upgrade the Horn Lake- Allen (TVA) 161kV line in The following transactions were included in this Facilities Study: Confirmed Reservations OASIS# PSE MW Begin End NRG Power Marketing /01/98 01/01/ (delisting) Entergy Services, Inc. (EMO) 1 07/02/98 07/01/ Ameren Energy Inc /12/99 01/01/ Entergy Services, Inc. (EMO) /01/00 01/01/ South Mississippi Electric Power 75 01/01/01 06/01/09 Assoc Entergy Services (EMO) /01/01 01/01/ East Texas Electric Cooperative 31 01/01/01 01/01/ Municipal Energy Agency of 13 05/01/01 06/01/10 Mississippi Municipal Energy Agency of 13 05/01/01 06/01/10 Mississippi (renewal) City Water & Light,Jonesboro 83 01/01/03 01/01/ (renewal) City Water & Light,Jonesboro /01/03 01/01/ East Texas Electric Cooperative 50 01/01/05 01/01/ East Texas Electric Cooperative 50 01/01/05 01/01/ East Texas Electric Cooperative 75 01/01/05 01/01/ Tennessee Valley Auth BPT 73 09/01/03 09/01/ (renewal) City Water & Light,Jonesboro 83 01/01/10 01/01/ (renewal) City Water & Light,Jonesboro /01/10 01/01/ Entergy Services, Inc. (EMO) /01/03 02/01/ Entergy Services, Inc. (EMO) 91 02/01/03 02/01/ Entergy Services, Inc. (EMO) /01/03 02/01/ Entergy Services, Inc. (EMO) /01/04 05/01/ Entergy Services, Inc. (EMO) 20 06/01/10 06/01/29 Page 6 of 29

7 OASIS# PSE MW Begin End Cleco Power LLC (Gen) 12 08/01/03 01/01/ Cleco Power LLC (Gen) 7 08/01/03 01/01/ Cleco Power LLC (Gen) 7 08/01/03 01/01/ Entergy Services, Inc. (EMO) 80 08/01/04 02/01/ Entergy Services, Inc. (EMO) /01/04 02/01/ NRG Power Marketing 91 04/01/04 04/01/ Merrill Lynch Commodities 11 01/01/00 01/01/ (delisting) Entergy Services Inc. (EMO) 1 06/01/07 06/01/ Entergy Services, Inc. (EMO) /01/06 01/01/ (renewal) East Texas Electric Cooperative 75 01/01/09 01/01/ (renewal) East Texas Electric Cooperative 50 01/01/09 01/01/ (renewal) East Texas Electric Cooperative 50 01/01/09 01/01/ ( Entergy Services Inc. (EMO) 1 06/01/07 06/01/30 ) (delisting) CLECO Power Marketing 35 01/01/06 01/01/ Plum Point Energy Associates 40 03/01/10 03/01/ Plum Point Energy Associates 35 03/01/10 03/01/ Plum Point Energy Associates 50 03/01/10 03/01/ Plum Point Energy Associates 50 03/01/10 03/01/ Entergy Services, Inc. (EMO) /01/06 01/01/ Entergy Services, Inc. (EMO) 50 06/01/07 06/01/ Entergy Services, Inc. (EMO) /01/07 06/01/ Entergy Services, Inc. (EMO) /01/08 06/01/ Entergy Services, Inc. (EMO) /01/07 06/01/ Entergy Services, Inc. (EMO) /01/07 02/01/ CLECO Power Marketing 10 01/01/06 01/01/ ( ) Plum Point Energy Associates 5 03/01/10 03/01/ Municipal Energy Agency of 40 06/01/10 06/01/40 Mississippi Morgan Stanley Commodities Group /01/07 01/01/ Morgan Stanley Commodities Group /01/07 01/01/ City of Conway 25 03/01/10 03/01/ Louisiana Generating LLC 11 03/01/06 03/01/11 Page 7 of 29

8 OASIS# PSE MW Begin End Louisiana Generating LLC 8 03/01/06 03/01/ Louisiana Generating LLC 5 03/01/06 03/01/ CLECO Power LLC /01/06 12/01/ Osceola Light & Power 9 09/01/09 09/01/ Constellation Energy Group 34 01/01/06 01/01/ Constellation Energy Group 34 01/01/06 01/01/ Constellation Energy Group 17 01/01/06 01/01/ ( Constellation Energy Group 17 01/01/06 01/01/36 ) Arkansas Electric Cooperative Corp /01/07 01/01/ NRG Power Marketing 13 10/01/07 10/01/ ( City of Prescott 22 04/01/06 04/01/09 ) CLECO Power 11 04/01/06 04/01/ NRG Power Marketing /01/07 06/01/ (renewal) Louisiana Energy & Power Authority 6 02/01/07 02/01/ NRG Power Marketing 5 09/01/06 09/01/ Constellation Commodities Group 42 08/01/06 08/01/ Constellation Commodities Group /01/07 01/01/ Constellation Commodities Group /01/07 01/01/ South Mississippi Electric Power /01/10 04/01/40 Assoc (renewal) Morgan Stanley Commodities Group /01/08 01/01/ (renewal) Morgan Stanley Commodities Group /01/08 01/01/ South Mississippi Electric Power /01/10 04/01/40 Assoc NRG Power Marketing 92 01/01/07 01/01/ ( City of North Little Rock 60 03/01/10 03/01/40 ) NRG Power Marketing /01/07 01/01/ NRG Power Marketing /01/07 01/01/ Constellation Commodities Group 22 01/01/07 01/01/ Constellation Commodities Group 50 01/01/07 01/01/ NRG Power Marketing /01/07 01/01/ Constellation Commodities Group 57 01/01/07 01/01/08 Page 8 of 29

9 OASIS# PSE MW Begin End (delisting) Entergy Services, Inc. (EMO) 1 01/01/07 01/01/ Constellation Commodities Group /01/07 01/01/ East Texas Electric Cooperative 50 03/01/10 03/01/ Cargill Alliant /01/08 01/01/ South Mississippi Electric Power /01/07 01/01/08 Assn Arkansas Electric Cooperative Corp /01/07 01/01/ Arkansas Electric Cooperative Corp /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 05/01/ Entergy Services, Inc. (EMO) /01/08 05/01/ (renewal) MidAmerican Energy 50 01/01/07 01/01/ (renewal) MidAmerican Energy 50 01/01/07 01/01/ (renewal) MidAmerican Energy 50 01/01/07 01/01/ (renewal) MidAmerican Energy 50 01/01/07 01/01/ Arkansas Electric Cooperative Corp. 72 / /01/07 01/01/ Arkansas Electric Cooperative Corp. 77 / 84 01/01/08 01/01/ Arkansas Electric Cooperative Corp /01/08 01/01/ (renewal) NRG Power Marketing /01/07 03/01/ (renewal) NRG Power Marketing 3 07/01/07 07/01/ (renewal) NRG Power Marketing /01/08 01/01/ NRG Power Marketing /01/07 06/01/ ( Constellation Energy Group 9 01/01/07 01/01/08 ) Entergy Services, Inc. (EMO) 3 01/01/07 09/21/ NRG Power Marketing /01/08 01/01/ NRG Power Marketing /01/08 01/01/ (renewal) MidAmerican Energy /01/07 03/01/ Entergy Services, Inc. (EMO) /01/07 06/01/ Entergy Services, Inc. (EMO) /01/09 06/01/ Cargill Power /01/08 01/01/ (renewal) NRG Power Marketing /01/08 01/01/ NRG Power Marketing /01/08 01/01/ NRG Power Marketing /01/07 09/01/08 Page 9 of 29

10 OASIS# PSE MW Begin End NRG Power Marketing /01/09 01/01/ CLECO Power LLC 10 10/01/07 10/01/ (renewal) Constellation Energy Group 6 06/01/07 06/01/ (renewal) Constellation Energy Group 70 06/01/07 06/01/ (renewal) Louisiana Energy & Power Authority 2 06/01/07 06/01/ Louisiana Energy & Power Authority 3 01/01/09 01/01/ Louisiana Energy & Power Authority 5 01/01/09 01/01/ Louisiana Energy & Power Authority 12 01/01/09 01/01/ East Texas Electric Coop /01/10 01/01/ NRG Power Marketing /01/09 01/01/ Constellation Energy 50 01/01/08 01/01/ Constellation Energy 25 01/01/08 01/01/ East Texas Electric Coop /01/10 01/01/ (renewal) South Mississippi Electric Power 75 06/01/09 06/01/11 Assn South Mississippi Electric Power /01/10 06/01/11 Assn Entergy Services, Inc. (EMO) 10 11/01/07 11/01/ NRG Power Marketing /01/08 01/01/ NRG Power Marketing /01/08 07/01/ Entergy Services, Inc. (EMO) /01/05 09/01/ (renewal) Ameren Energy, Inc /01/07 06/01/ Entergy Services (EMO) /01/08 01/01/ NRG Power Marketing /01/08 07/01/ (renewal) NRG Power Marketing /01/08 09/01/ (renewal) Cargill Power Markets, LLC /01/09 01/01/ (renewal) Cargill Power Markets, LLC /01/09 01/01/ NRG Power Marketing /01/08 01/01/ (renewal) NRG Power Marketing /01/09 01/01/ (renewal) NRG Power Marketing /01/09 01/01/ (renewal) NRG Power Marketing 92 01/01/10 01/01/ Constellation Energy 22 01/01/08 01/01/ Constellation Energy 35 01/01/08 01/01/ Constellation Energy 75 01/01/08 01/01/ Constellation Energy 75 01/01/08 01/01/09 Page 10 of 29

11 OASIS# PSE MW Begin End Constellation Energy 25 01/01/08 01/01/ Entergy Services, Inc. (EMO) 75 08/01/07 01/01/ Entergy Services, Inc. (EMO) 86 08/01/07 01/01/ Entergy Services, Inc. (EMO) 68 08/01/07 01/01/ Entergy Services, Inc. (EMO) 78 08/01/07 01/01/ Entergy Services, Inc. (EMO) 11 08/01/07 01/01/ Entergy Services, Inc. (EMO) 69 08/01/07 01/01/ Entergy Services, Inc. (EMO) 14 08/01/07 01/01/ (renewal) Merrill Lynch Commodities 85 11/01/07 11/01/ (renewal) Merrill Lynch Commodities 4 11/01/07 11/01/ Arkansas Electric Cooperative Corp /01/08 01/01/13 / Constellation Energy 50 01/01/08 01/01/ Constellation Energy 25 01/01/08 01/01/ East Texas Electric Cooperative 10 01/01/08 01/01/ Westar Energy 6 10/01/07 01/01/ East Texas Electric Cooperative 29 01/01/08 01/01/ East Texas Electric Cooperative 35 01/01/08 01/01/ (delisting) East Text Electric Cooperative 1 01/01/08 01/01/ (renewal) NRG Power Marketing /01/11 01/01/26 Pre-888 Transactions OASIS # PSE MW Begin End East Texas Electric Cooperative 55 01/01/06 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) 59 01/01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/38 Page 11 of 29

12 OASIS # PSE MW Begin End Entergy Services, Inc. (EMO) 64 01/01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) 65 01/01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) 61 01/01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/ Entergy Services, Inc. (EMO) /01/07 01/01/38 Study Queue OASIS PSE MW Begin End Louisiana Energy & Power /01/05 09/01/10 Authority Louisiana Energy & Power 45 09/01/05 09/01/10 Authority Louisiana Energy & Power 13 09/01/05 09/01/10 Authority American Electric Power Service /01/08 01/01/10 Corp Aquilla Networks MPS 75 03/01/09 03/01/ Aquilla Networks MPS 75 03/01/09 03/01/ Aquilla Networks MPS 75 03/01/09 03/01/ Aquilla Networks MPS 75 03/01/09 03/01/ Louisiana Energy & Power Auth /01/09 01/01/ Muni energy Agcy of Miss 20 06/01/11 06/01/ Mid American Energy /01/07 09/01/ Mid American Energy /01/07 09/01/ Mid American Energy /01/08 01/01/ Mid American Energy /01/08 01/01/ Entergy Services /01/08 01/01/58 Page 12 of 29

13 OASIS PSE MW Begin End Constellation Energy 60 02/01/11 02/01/ City of Conway 50 02/01/11 02/01/ Constellation Energy 30 02/01/11 02/01/ Louisiana Energy and Power 50 02/01/11 02/01/16 Authority NRG Power Marketing 20 02/01/11 02/01/ NRG Power Marketing /01/10 01/01/ NRG Power Marketing /01/10 01/01/ NRG Power Marketing /01/10 01/01/ Southwestern Electric Cooperative 78 05/01/10 05/01/ Constellation Energy 60 04/01/12 04/01/ Constellation Energy 30 04/01/12 04/01/ Conway Corporation 50 04/01/12 04/01/ NRG Power Marketing /01/08 01/01/ Entergy Services (EMO) 1 01/01/08 01/01/ Entergy Services (EMO) 1 01/01/08 01/01/ Entergy Services (EMO) /01/12 07/01/ Constellation Energy 50 01/01/09 01/01/ Constellation Energy 30 01/01/09 01/01/ Constellation Energy 20 01/01/09 01/01/ NRG Power Marketing /01/09 01/01/ Muni Energy Agcy of Miss 20 01/01/11 01/01/26 SAFETY AWARENESS 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. Should the work contained within this Facility Study be approved, a detailed Safety Plan will be formulated and incorporated within the project plan. 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 Page 13 of 29

14 the highest priority for all projects. All Entergy and Contract employees must follow all applicable safe work procedures. Page 14 of 29

15 SCOPE DETAILS 4.1 Transmission Substations Bogalusa 230 kv Substation Electrical: Replace 1600A breaker #S2520 by 3000A, 63kA breaker as well as the associated breaker disconnect switches to match the breaker rating. Multi ratio CTs would be ordered in consultation with Relay Design group. Also replace the three disconnect switches in that bay, including one ground switch, one motor operator, and associated insulators. Upgrade the bus work to 3000A as required. Site: No site work is required Foundations: Install grounding and conduit as required for the new breaker and disconnect switches. Relay Design: The control of breaker S2520 is located on the Adam Creeks Line B/ Breaker S2520 panel. Replace 230kV MOS S2093 by a 3000A MOS, a new MOS Control panel will be installed. Replace SEL 2020 Communication Processor by a SEL 2032 one. With new breaker and MOS RTU needs additional alarms. Settings and RTU Configuration: Review / revise bus differential and line to Adams Creek settings Perform configuration for extra alarms from the new breaker. Page 15 of 29

16 Equipment Quantity Lead 230 KV Breaker 1 26 weeks Disconnects 3 18 weeks MOS Panel 1 6 Weeks * Lead times are as of June 2007 Tentative High Level Construction & Installation plan with associated outages: Week one: Mobilize; receive the HV breaker, HV Switches, miscellaneous materials. Pre-build new HV Switches. Week two: Begin outage on Adams Creek (Line B ), remove and replace breaker # S2520. Outage Duration on Adams Creek (Line B ) will be a crippling outage for (4) weeks. Week three: Install conduits, and Protection and Control Cables to new Breaker # S2520. Week four: Replace 230kV Line Disconnect, Ground Sw. # S0611, and associated bus work. Revise settings and complete RTU configuration. Gas and mechanically test new Breaker # S2520. Week five: Perform functional test and checkout, CT saturation and polarization. Replace 230kV Bus Disconnect on the 230kV Operating Bus. Outage duration for the Operating Bus will be (4) days. Week six: Replace 230kV Inspection Bus Disconnect Switch # S2093 and associated Bus. This will include the replacement of the Motor Operator, conduits, and control cables. Outage duration for the 230kV Inspection Bus will be (5) days. Week seven: Clean-up, disposition all materials, and demobilize. Begin Project Closeout activities. Due to increased power flow on line between Ray Braswell and Baxter Wilson 500 kv line, requirement is to replace existing 2000A breakers and disconnect switches by 3000A and 63 ka interrupter rating at Ray Braswell and Baxter Wilson Substations. Page 16 of 29

17 4.1.2 Ray Braswell 500 kv: Site and Foundation: The foot print of the new breaker will not be the same as existing one. Breaker foundations will be modified to install the new breaker. New conduit will run from the existing cable trench and 4/0 copper shall connect to new beaker to the existing ground grid. Limestone will be required to restore ground disturbed by movement of vehicles and foundation work. Extra bus supports may be required between new breakers and breaker switches. Assume that the existing grounding grid can sufficiently meet touch and step voltage requirements with the new fault current. Electrical: Replace the following breakers and switches: Remove existing breakers and external CTs Install Breakers: J4928 and J4920 (replace by 3000A, multi CT ratios, 63 ka, dead tank design) Install motorized switches: J4919, J4921, J4927, and J4929 (3000A) Install associated insulators, bus, connectors and hardware to match 3000A rating Install low bus supports if required. Long Lead Material Ray Braswell 500kV Substation Quantity Material Description *Lead Time (weeks) 2 500kV dead tank breakers kV switches 26 Relaying: The scope of this project is to replace two (2) 3000A 500kV breakers at Ray Braswell. The existing breakers are underrated and will be replaced with 3000A, 63KA breakers. Install two (2) 3000A 500kV breakers. Install new shielded control cables to each breaker. No control panels will be replaced during this project. Install four (4) 3000A 500kV motor operators. Install new shielded control cables to operators. No MOS panels will be replaced during this project. Kirk key Interlock between breaker & switches will need to be replace Control house equipment is adequate AC and DC panels are adequate Page 17 of 29

18 Add points on S cards with accessories to the RTU A GE Harris D20 RTU will require a configuration package Long Lead Material Ray Braswell 500kV Relay Quantity Material Description *Lead Time (weeks) RTU cards 6 8 * Lead time as of 2/05/07 A. Relay Settings: Work is required as the ratio for new breakers to be 3000/5. B. RTU configuration: Some alarms may be added as a result configuration for new cards and reassignment of existing points may be required. Ensure that the CT ratios are identified with over load rating to match with surrounding breaker associated existing protection to minimize the impact of changed breaker rating Ensure that the control schematic and breaker control cabinet orientation aligns with the existing conduits Design for extra alarms for RTU and develop edit sheet RTU configuration and settings: Should the CT ratios be matched with the surrounding breakers, no changes in settings should be required for the surrounding line protection Revise Ray B BW line protection settings corresponding to 3000A CT ratios Revise RTU configuration to accommodate additional breaker alarms Construction: An approximate nine to ten week outage will be required on the BWSES to Ray Braswell 500 kv line in order to replace the breakers, switches and associated bus and relay equipment. To minimize outage time, work will be performed at both substations concurrently. Separate crews will be working at each substation simultaneously. Foundations will have to be replaced as well and will be constructed during the outage time frame. Page 18 of 29

19 4.1.3 Baxter Wilson 500 kv: Site and Foundation: The foot print of the new breaker will not be the same as existing one. Breaker foundations will be modified to install the new breaker. New conduit will run from the existing cable trench and 4/0 copper shall connect to new beaker to the existing ground grid. Limestone will be required to restore ground disturbed by movement of vehicles and foundation work. Extra bus supports may be required between new breakers and breaker switches. Assume that the existing grounding grid can sufficiently meet touch and step voltage requirements with the new fault current. Electrical: Replace the following breakers and switches: Remove existing breaker J2230 and external CTs Install Breaker: J2230 (replace by 3000A, multi CT ratios, 40 ka, dead tank design) Replace motorized switches: J2228, J2229, J2232, J2234, K2283, and J2249 (3000A) (including one ground switch) Install associated insulators, bus, connectors and hardware to match 3000A rating Install low bus supports if required. Long Lead Material Baxter Wilson 500kV Substation Quantity Material Description *Lead Time (weeks) 1 500kV dead tank breakers kV switches 26 Relaying: The scope of this project is to replace two (2) 3000A 500kV breakers at Baxter Wilson. The existing breakers are underrated and will be replaced with 3000A, 63KA breakers. Install one (1) 3000A 500kV breaker. Install new shielded control cables to each breaker. No control panels will be replaced during this project. Remove four (4) 3000A 500kV CT. Install new shielded control cables to Breaker CTs. Install six (6) 3000A 500kV motor operators. Install new shielded control cables to operators. No MOS panels will be replaced during this project. Kirk key Interlock between breaker & switches will need to be replace Page 19 of 29

20 Control house equipment is adequate AC and DC panels are adequate Add points on S cards with accessories to the RTU A GE Harris D20 RTU will require a configuration package Long Lead Material Baxter Wilson 500kV Relay Quantity Material Description *Lead Time (weeks) RTU cards 6 8 * Lead time as of 2/05/07 Ensure that the CT ratios are identified with over load rating to match with surrounding breaker associated existing protection to minimize the impact of changed breaker rating Ensure that the control schematic and breaker control cabinet orientation aligns with the existing conduits Design for extra alarms for RTU and develop edit sheet RTU configuration and settings: Should the CT ratios be matched with the surrounding breakers, no changes in settings should be required for the surrounding line protection Revise Ray B BW line protection settings corresponding to 3000A CT ratios Revise RTU configuration to accommodate additional breaker alarm Construction: An approximate nine to ten week outage will be required on the BWSES to Ray Braswell 500 kv line in order to replace the breakers, switches and associated bus and relay equipment. To minimize outage time, work will be performed at both substations concurrently. Separate crews will be working at each substation simultaneously. Foundations will have to be replaced as well and will be constructed during the outage time frame. Two week outages to the BWSES - Perryville 500 kv line and the BWSES East 500 kv bus as well as two weeks outages to the Ray Braswell Lakeover 500 kv line and Ray Braswell 500 kv bus No. 2 will be required. Page 20 of 29

21 4.1.4 Horn Lake Substation: Requirement is to replace line relaying on 161 kv TH Allen line and the communication equipment. This is contingent on TVA agreement depending on what protection they would install. Since no fiber optic OPGW is being installed as part of the line rebuild, assuming that either Power Line Carrier or phone circuit will be used. Electrical/Site Foundation: None Relaying: Replace existing line relay panel and communication equipment. Assumption is made that TVA will install the same panel as Entergy decides at the other end of the line and Entergy estimate does not include the cost of replacing panel at TH Allen. Construction: An outage of one week will be required to replace the panel and TVA is assumed to work concurrently and share the relay settings. 5. Upgrades to Transmission Lines: Hernando-Coldwater-Senatobia 115kV transmission line Hernando-Coldwater 115kV transmission line upgrade from a capacity of 108MVA to at least 131MVA. The existing line is a wooden structure design with 333 kcmil conductors. This upgrade would require removal and replacement of the 8.15 mile line. Approximately 82 structures will be replaced and will be directly embedded. This estimate includes removal of the existing structures and replacing them with new concrete pole structures. All design and construction will be completed in accordance with current Entergy loading, clearance and construction criteria. The existing line conductors are 333 kcmil which is being upgraded to 666 ACSR. Page 21 of 29

22 Long Lead Items The following long lead equipment is required for this work: Equipment Quantity Lead time Concrete 82 each 18 weeks Line insulators 240 each 12 weeks 666 ACSR conductor 180, 000 lbs 22 weeks OPGW 42,786 ft 17 weeks Lead times are as of January 2008 Coldwater-Senatobia 115kV transmission line must be upgraded from a capacity of 108MVA to at least 118MVA. The existing line is a wooden structure design with 333 kcmil conductors. This upgrade would require removal and replacement of the 5.6 mile line. Approximately 52 structures will be replaced and will be directly embedded. This estimate includes removal of the existing structures and replacing them with new concrete pole structures. All design and construction will be completed in accordance with current Entergy loading, clearance and construction criteria. The existing line conductors are 333 kcmil which is being upgraded to 666 ACSR. Long Lead Items The following long lead equipment is required for this work: Equipment Quantity Lead time Concrete 52 each 18 weeks Line insulators 168 each 12 weeks 666 ACSR conductor 124,000 lbs 22 weeks OPGW 29,568 ft 17 weeks Lead times are as of January 2008 Page 22 of 29

23 5.2.1 Upgrade the Horn Lake-Allen (TVA) 161kV transmission line Rebuild line section from Horn Lake substation to the state border (approximately 5.9m) with capability to carry a minimum of 292 MVA (1047A). Transmission Line: Remove the 5.9 miles of existing Entergy transmission line and rebuild along the same centerline with a single circuit bundled (2) 954 MCM 54/7 ACSR "Cardinal" conductor. Approximately 58 structures will be replaced and will be directly embedded or have vibratory pile foundations. This estimate includes removal of the existing structures and replacing them with new steel pole structures. All design and construction will be completed in accordance with current Entergy loading, clearance and construction criteria. The existing line conductors are 666 kcmil which is being upgraded to bundled (2) 954 ACSR Cardinal conductor and the existing 3/8" H.S.G. shield wire will be replaced with 7#7 Alumoweld (no fiber optic OPGW). The existing TVA owned structures located in Entergy territory will remain, and the Entergy structures will be built adjacent to and on each side of the TVA 500kV lattice towers to accommodate re-conductoring with 2 wire bundle 954 MCM 54/7 ACSR "Cardinal" conductors. Long Lead Items The following long lead equipment is required for this work: Equipment Quantity Lead time Steel Poles(48 Structures) 66 each 18 weeks Line insulators 220 each 12 weeks "Cardinal conductor 244,000 lbs 22 weeks 7 No. 7 shield wire 47,000 ft 17 weeks Caissons 10 each 18 weeks Lead times are as of January 2008 Assumption This estimate does not include the rebuilding the 161kV transmission line segment in Tennessee. A CCN permit is not required, however exemptions may be required. Final foundation and structure design will be based on survey results, soil borings, and loading conditions to assure compliance with Entergy design criteria. There will not be any clearance problems with the slack spans through the windows of the existing TVA lattice towers. Page 23 of 29

24 COSTS The ICT has reviewed and determined whether each required upgrade will be considered a Base Plan Upgrade or a Supplemental Upgrade. For more information on cost responsibility for Base Plan and Supplemental Upgrades, see Attachment T to Entergy s OATT. The costs shown in the table include overheads and AFUDC, but do not include tax gross up that may apply to the project, current TGU rate is %. The costs shown are considered to be accurate to within +/-25%. Description Projected Costs in 2008 dollars w/o escalation Estimated Completion Year Total Cost 2008 Base Plan Upgrades Supplemental Upgrades Upgrades to Bogalusa S/S March 2009 $858,208 $858,208 Upgrades to Ray Braswell S/S March 2009 $3,486,297 $3,486,297 Upgrades to Baxter Wilson S/S March 2009 $2,672,102 $2,672,102 Upgrade to Hernando- June 2009 Coldwater 115kV T- line $4,890,640 $4,890,640 Upgrade to Coldwater- June 2009 Senatobia 115kV T- line $3,678,974 $3,678,974 Upgrade at Horn Lake Substation April 2010 $465,000 $465,000 Upgrade the Horn Lake-Allen April 2010 (TVA) 161kV transmission line. $7,150,073 $7,150,073 Total with OH and excluding TGU $23,201,294 $7,615,073 $15,586,221 SCHEDULE A detailed schedule will be prepared subsequent to customer approval. The line upgrades are dependent on obtaining outages for the line work. If outages cannot be obtained or must be sequenced due to seasonal requirements, additional time will be required to complete the upgrades. The following are rough durations: Page 24 of 29

25 Project Definition Includes surveys, soil borings, and Project Execution Plan 16 Weeks Substations: Includes design, material procurement, and construction Bogalusa 40 weeks Baxter Wilson 40 weeks Ray Braswell 40 weeks Horn Lake 40 weeks Transmission Lines: Hernando Coldwater 60 Weeks Coldwater Senatobia 60 Weeks Horn Lake Alan (TVA) 60 Weeks Notes to Duration Schedules: All construction work requiring outages will be performed during offpeak load season. Line outages will be discussed with the SOC and TOC and the assumption is made that line outages will be executed as planned. However, last minute denial of outages by the SOC/TOC along with resulting schedule delay is possible. Transmission Line project will begin subsequent to Definition phase Project Execution Plan Schedule durations are high level estimates at this time. Upon project approval, a detailed schedule will be produced Based on duration schedule the upgrades identified for this Facility Study will not be complete till April 2010, past the requested start date for this transmission service. Page 25 of 29

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