FACILITIES STUDY ICTT /-143/-144/-145 TRANSMISSION SERVICE REQUEST OASIS _74_76_80

Transcription

1 TRANSMISSION LINE & SUBSTATION PROJECTS COMPANY: ENTERGY SERVICES, INC. CUSTOMER ENTERGY SERVICES, INC. FACILITIES STUDY EJO NO. F4PPLA0351 ICTT /-143/-144/-145 TRANSMISSION SERVICE REQUEST OASIS _74_76_80 Revision: 0 Rev Issue Date A 5/09/11 B 5/13/11 Description of Revision Submitted to TPD, JET, and Director for review/comments Approved with Revisions per comments from JET,TPD, and Director Prepared By RP Approved By 0 5/16/11 ICT Determines Upgrade Classification SM BR RP RG RG

2 TABLE OF CONTENTS 1. PROJECT SUMMARY Background and Project Need Scope Summary Cost Summary Schedule Summary... 4 SAFETY REQUIREMENTS & GENERAL ASSUMPTIONS GENERAL SCOPE OF WORK Upgrade the Ninemile Southport 230kV Lines 1 and Upgrade the Gretna-Harvey 115kV Line COST UPGRADE CLASSIFICATION SCHEDULE RISK ASSESSMENT CONFIRMED RESERVATIONS PRE-888 TRANSACTIONS STUDY QUEUE ATTACHMENTS Table of Acronyms Drawings Duration Schedule

3 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 Entergy (EES) to Entergy (EES) to evaluate the Entergy Services request for 584MW of yearly network transmission service. ATC for OASIS was evaluated with the proposed undesignations cited in OASIS requests , , and The time period for this transfer is from 1/1/2015 until 1/1/2045. The direction of the transaction is EES to EES. The study was performed on the latest available winter and summer peak seasonal models 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. 1.2 Scope Summary The Facilities Study has identified some transmission constraints Upgrade the Ninemile - Southport 230kV transmission lines 1 and 2 The Ninemile - Southport 230kV transmission line 1 / 2 overloads for the loss of the Ninemile - Southport 230kV transmission line 2 / 1. It is required that the Ninemile - Southport 230kV transmission lines 1 and 2 be upgraded from 641MVA to at least 747MVA. The proposed upgrade rating is 780MVA. The amount of capacity created by this upgrade is 139MW for each line, and the customer s use of the capacity created is 109MW on each line Upgrade the Harvey - Gretna 115kV transmission line The Harvey - Gretna 115kV transmission line overloads for the loss of the Ninemile - Westwego 115kV or Ninemile - Estelle 230kV transmission line. It is required that the Harvey - Gretna 115kV transmission line be upgraded from 120MVA to at least 161MVA. The proposed upgrade rating is 228MVA. The amount of capacity created by this upgrade is 108MW, and the customer s use of the capacity created is 12MW Pmax of the generating plant is exceeded Only 570MW is available (beyond which Pmax of the generator would be exceeded). 3

4 1.3 Cost Summary The estimated total project cost in 2011 dollars is $2,262,916. This does not include Tax Gross Up, which may apply (rate at this time is 30%). The ICT has assigned $0 as Base Case upgrades and $2,262,916 as Supplemental Upgrade based on Attachment T of Entergy s Open Access Transmission Tariff (OATT). 1.4 Schedule Summary The requested in-service date is January 1, The duration of work scoped and estimated below is eighteen (18) months starting from June 4, 2012, and is expected to be completed by December SAFETY REQUIREMENTS & GENERAL ASSUMPTIONS Safety: 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. General Assumptions: Sufficient time will be allowed in approving the project, enabling Entergy to prepare a Project Execution Plan (PEP) and be able to complete the project, as per the schedule described below. The use of a 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. 4

5 3. GENERAL SCOPE OF WORK 3.1 Upgrade the Ninemile Southport 230kV Lines 1 and 2 Transmission Line Increase the capacity of the Southport - Ninemile line to 747MVA. This will be accomplished by removing the existing 1780 ACSR conductor and replacing it with a 1272 ACSS conductor. The 1272 ACSS conductor is rated 1957A, 780MVA at 230kV, 347 F. Remove approximately 10,100 (21,008 lbs.) of existing 1780 ACSR conductor on line 1 of the Southport - Ninemile line. Remove approximately 9,150 (19,032 lbs.) of existing 1780 ACSR conductor on line 2 of the Southport to Ninemile line. Install approximately 11,040 (15,787 lbs.) of 1272 ACSS conductor on line 1 of the Southport - Ninemile line. Install approximately 10,005 (14,307 lbs.) of 1272 ACSS conductor on line 2 of the Southport - Ninemile line. Remove and replace approximately 72 dead end insulators and 12 tangent (braced post) insulators. It is assumed that the shield wire is adequate and does not require replacement. It is assumed that the river crossing is currently strung with an adequate conductor. It is assumed that all structures are adequate and do not require replacement. Spans requiring remediation: Structure 10 - Southport Sub (Ninemile Line 1 bay). Structure 10 - Southport Sub (Ninemile Line 2 bay). Ninemile Sub (Southport line 1 bay) - Structure 7. Ninemile Sub (Southport line 2 bay) - Structure 7. 5

6 Long Lead Time Equipment Quantity Material Description *Lead Time (weeks) 30,094 lbs ACSS conductor each Dead-end insulators each Tangent insulators *As of 5/13/2011 Relaying No Relay upgrades are required. RTU configuration and settings Southport 230kV Substation: Update four (4) breaker control settings. Update two (2) line panel settings. Update RTU configuration. Joilet 230kV Substation: Update one (1) line panel setting. Update RTU configuration. Labarre 230kV Substation: Update one (1) line panel setting. Update RTU configuration. Ninemile 230kV Substation: Update four (4) breaker control settings. Update two (2) line panel settings. Update two (2) bus differential settings. Update RTU configuration. Substation Scope Site: No site work is required. Foundation: No foundation work is required. Electrical: South Port 230kV Substation: Increase capacity of all components in the ring and Ninemile lines to at least 747MVA or 1875A. 6

7 Replace 1780MCM ACSR line bay bus and line bay risers with two (2) 1780 MCM ACSR conductors in Ninemile 1 line bay. Replace 1780MCM ACSR breaker S2708 and S4169 jumpers with two (2) 1780 MCM ACSR conductors. Replace 1780MCM ACSR line bay bus and line bay risers with two (2) 1780 MCM ACSR conductors in Ninemile 2 line bay. Ninemile 230kV Substation: Increase capacity of all line bay components to at least 747MVA or 1875A Replace 1780MCM ACSR line bay bus and line bay risers with two (2) 1780 MCM ACSR conductors in Southport 1 line bay. Replace 2336MCM ACAR breaker S2037 and S2034 jumpers with two (2) 1780 MCM ACSR conductors. Replace 1780MCM ACSR line bay bus and line bay risers with two (2) 1780 MCM ACSR conductors in Southport 2 line bay. Construction and Outage Plan If this project is approved and enters the Energy Delivery 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 use the preferred supplier resources, perform a competitive bid process to award the work to an Entergy-approved contractor, or to allow internal Entergy Resources to perform the work. This project does not consist of any site, foundation, grounding, or conduit work. All work associated with this job will need to be done under an outage. Normally, outages on 230kV facilities require a half year s advanced notice, with no guarantees that said outage will be granted at the time requested. This poses risk to all schedules. The sequence of work will consist of multiple crews. There will be transmission line crews performing work on the Southport end of the line and transmission line crews working on the Ninemile end of the line. At the same time, there will be a substation crew changing out jumpers on the breakers and traps in order to complete the upgrade work on each line before energizing them. 7

8 Ninemile - Southport 2: For the installation of the new 1272 ACSS conductor on the transmission line Ninemile - Southport 2, an outage consisting of several weeks duration will be required. For the work on the Ninemile - Southport 2 line, outages will be needed on the south bus at Ninemile, the line going to the SVC at Ninemile, and the section of the ring bus between breakers S3191 and S2708, which de-energizes the Ninemile - Southport line 1. This outage is needed when working in the Southport substation and working around the back span dead end on the west bank side of the river. The plan is to mobilize a transmission line crew to start the reconductoring work on the Ninemile end first. The crew will start restringing the conductor across the south bus. The crew will then move to reconductoring the section over the SVC. Then, the crew will continue reconductoring the transmission line up to the span before the back span dead end on the west bank side of the river. At this time, a second transmission line crew will be mobilized to the Southport end to reconductor the span of line in the substation, and the crew on the Ninemile side will complete the reconductoring to the back span dead end and tie the new 1272 ACSS into the river crossing conductor. During this time of the reconductoring, the Ninemile - Southport 1 line will need to be deenergized. While the crew is reconductoring in the Southport substation, they will need to be aware that the line dead ends on the same structure as the transformer. The transformer will be energized; therefore, designated spotters will need to be used during the entire time the work is being performed. Replace Jumper on Trap and Breaker (S2708) Ninemile - Southport 2 (Southport Side): During the outage on the Ninemile - Southport 2 line, the jumpers on the trap will be replaced with bundled 1780 ACSR conductor. It is estimated that the substation crew will mobilize and start the work on the jumpers about one (1) week into the outage. When the crew makes up the jumpers on the trap, they shall leave the jumpers long on the line side so the second transmission line crew can make up the jumper to the new 1272 ACSS dead end shoes once the reconductoring is complete. Once the jumpers on the trap are replaced, the substation crew will start replacing the jumper on breaker S2708 with bundled 1780 ACSR. This work will be completed prior to starting the transmission line reconductoring portion inside of Southport substation. Replace Jumper on Trap Ninemile - Southport 2 (Ninemile Side): This work will also be done during the outage for the reconductoring of the transmission line. Once the substation crew has completed the work on the Southport end of the line, they will mobilize to the Ninemile end to replace the jumpers on the trap. The transmission line crew should be clear of the Ninemile substation and the substation crew should have adequate space to replace the jumpers on the trap. Since the transmission line work will be 8

9 completed in this area, the substation crew will be responsible for making up the jumpers all the way to the new 1272 ACSS dead end shoe. The jumper will be replaced with bundled 1780 ACSR. A transition plate may be needed on the dead end shoe in order to attach the 1780 ACSR jumper terminals. Upon completion of reconductoring the Ninemile - Southport 2 line, replacing jumpers to the traps and replacing jumpers to the breaker, all phasing, checkouts and commissioning can be made. Once this work is completed, the transmission line crews and the substation crews will continue their work on the Ninemile - Southport 1 line. Ninemile - South Port 1: For the installation of the new 1272 ACSS conductor on the transmission line Ninemile - Southport 1, an outage consisting of several weeks duration will be required. For the work on the Ninemile - Southport 1 line, outages will be needed on the north bus at Ninemile, and the section of the ring bus between breakers S1488 and S2708, which de-energizes the Ninemile - Southport line 2. This outage is needed when working in the Southport substation and working around the back span dead end on the west bank side of the river. Once the work is completed on the Ninemile - Southport 2 line, the two (2) transmission line crews will resume work on the Ninemile - Southport 1 line. The crew on the Ninemile side will start by completing the reconductoring near the back span dead end, and the crew working in the Southport substation will resume work on the 1 line. Once this work is completed, the Ninemile - Southport 2 line can be energized. Then, the crew on the Ninemile end will continue reconductoring the next section of line. The transmission line crew that was working in the Southport substation will mobilize to the Ninemile side and will reconductor the section over the north bus. Once this work is completed, the two (2) crews will continue working until the lines is completely reconductored to 1272 ACSS conductor. Replace Jumper on Trap Ninemile - Southport 1 (Ninemile Side): During the outage on the Ninemile - Southport 1 line, the jumpers on the trap will be replaced with bundled 1780 ACSR conductor. When the crew makes up the jumpers on the trap, they shall leave the jumpers long on the line side so the second transmission line crew can make up the jumper to the new 1272 ACSS dead end shoes once the reconductoring is complete. This work will be completed prior to starting the transmission line reconductoring portion over the north bus at Ninemile substation. Replace Jumper on Trap Ninemile - Southport 1 (Southport Side): Once the jumpers on the trap are completed at Ninemile, the substation crew will mobilize back to Southport substation to replace the jumpers on the trap. The transmission line crew should be clear of the Southport substation and 9

10 the substation crew should have adequate space to replace the jumpers on the trap. Since the transmission line work will be completed in this area, the substation crew will be responsible for making up the jumpers all the way to the new 1272 ACSS dead end shoe. The jumper will be replaced with bundled 1780 ACSR. A transition plate may be needed on the dead end shoe in order to attach the 1780 ACSR jumper terminals. Upon completion of reconductoring the Ninemile - Southport 1 line and replacing jumpers to the traps, all phasing, checkouts and commissioning can be made once this work is completed. Replace Jumpers on Ninemile Breakers S2034 and S2037: These breakers have single conductor jumpers on one side of the breaker. These jumpers need to be changed to bundled 1780 ACSR. These breakers are setup in a breaker and a half scheme; therefore, outages should be able to be obtained easily to perform this work. This work will also be scheduled as fill in work for the substation crew while performing the rest of the work on the job. Replace Jumpers on Southport Breakers S4169: This breaker has single conductor jumpers on each side of the breaker. These jumpers need to be changed to bundled 1780 ACSR. This breaker is setup in a ring bus scheme; therefore, outages should be able to be obtained easily to perform this work. This work will be scheduled after all the reconductoring work is completed. 3.2 Upgrade the Gretna-Harvey 115kV Line Transmission Line No Line Upgrades required. Gretna 115kV Substation: Site: No site work required. Foundations: No foundation work required. Electrical: Increase capacity of the Ninemile Line Bay to 161MVA or 808A. Replace 600A switch S9187L with 2000 amp switch. 10

11 Relaying No Relay work required. Relay settings No Relay Settings required. Construction and outage plan: Replace Switch S9187L, Grounds Switch S2558GR, and Jumpers to Breaker S9187 The switch S9187L has a ground switch. Both of these switches must be replaced. The jumpers going to breaker S9187 are rigid and will need to be replaced once the new switch is installed. The tower is an AM 115kV tower. Therefore, the switch will need to be manufactured in such a way to be able to mount onto the tower. Also, the ground switch will need to swing towards the switch in order to maintain electrical clearances. 3.3 Construction Schedule and Required Outages: Week 1: No outages required. Transmission line crew mobilization to Ninemile. Week 2: Outage on Ninemile south bus. Outage on Ninemile - Southport 2. One shot on Ninemile - Southport 1. At the end of week 1, the south bus can be energized. Week 3: Outage on SVC Line. Continue outage on Ninemile - Southport 2. Continue one shot on Ninemile - Southport 1. Substation crew to replace jumpers on trap at Line 2 (Southport Side). At the end of week 2, the SVC line can be energized. Week 4: Continue outage on Ninemile - Southport 2. Continue one shot on Ninemile - Southport 1. Replace jumpers on breaker S2708 (Southport Side). Mobilize substation crew to Ninemile substation. Week 5: Continue outage on Ninemile - Southport 2. Continue one shot on Ninemile - Southport 1. 11

12 Replace jumpers on trap at Ninemile on Line 2. Mobilize second transmission line crew to Southport substation. Week 6: Continue outage on Ninemile - Southport 2. Outage on Ninemile - Southport 1. Substation crew to replace jumpers on breakers S2034 and S2037 at Ninemile. Week 7: Continue outage on Ninemile - Southport 2. Continue outage on Ninemile - Southport 1. Replace jumpers on trap at Ninemile on Line 1. At the end of week 7 the Ninemile - Southport 2 line can be energized. Subsequently mobilize substation crew to Southport substation to replace the jumpers on line trap on the Ninemile - Southport 1 Line. Mobilize transmission line crew from Southport to Ninemile. Week 8: Continue outage on Ninemile - Southport 1. Outage on north bus at Ninemile. One shot on Ninemile - Southport 2. Replace jumpers on trap at Southport on the Ninemile - Southport 1 Line. Week 9: Continue outage on Ninemile - Southport 1. One shot on Ninemile - Southport 2. At the end of week 9, the Ninemile - Southport 1 line can be energized. Substation crew off this week. Week 10: Outage on breaker S4169 at Southport substation. Replace jumpers. Required Outages for Gretna work: Week 1: No outages needed. Mobilize substation crew. Receive materials and pre-build switches. Week 2: Outage on Ninemile - Harvey tap - Gretna line bay. Replace switch, ground switch, and jumpers to breaker S

13 3.3.1 Assumptions 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 the design. Scheduled durations are high level estimates at this time. Upon project approval, a detailed schedule will be produced. Due to the layout of the lines and the bus configuration, both the 1 and 2 lines will need to be de-energized at the same time during part of the construction. Due to underground facilities (duct banks, pipe lines, etc.) near the back span dead end on the west bank side of the river, the use of matting materials will be required to cross them. Reuse existing structures. The capacity of the river crossing conductor is adequate for the new line rating. The shield wire will not be replaced with this project Safety Awareness Special Safety Considerations during Construction: 1. Entergy is firmly committed to prevention of injuries and accidents. Safety will always be of first consideration in all construction activities. Compliance with all safety and environmental rules promulgated by local, state and federal agencies and regulatory bodies must be adhered to without exception. Zero tolerance is expected. 2. Each employee is responsible and accountable for his/her safety compliance, both in facilities and work procedures. 3. Supervisors are responsible for job assignment, planning, and supervising to assure that safety rules and procedures are followed. 4. Clearances should be taken on all applicable equipment by the designated supervisor of the construction project. 13

14 5. All conductors and equipment shall be grounded according to Equipotential Zone Grounding Procedures, Entergy Safe Work Procedures, OSHA or contractors standards. The best applicable standard shall supersede given the specific task at hand. 6. Rubber goods utilized for working on or near energized conductors shall be tested and in acceptable working condition. 7. Insulated cover-up goods and guard structures shall be utilized when working over, under and near energized conductors. 8. Housekeeping will be performed on an ongoing basis, all materials and equipment will be stored in such a manner that the safety and protection of the equipment and any being in its presence is optimized. Debris and refuge shall be promptly disposed of in a proper manner/order. 9. Cranes, aerial baskets and hoisting equipment shall be positioned in such a manner as to not come in contact with any adjacent conductors or utilities according to all applicable safe work procedures. 10. Proper matting will be utilized to stabilize equipment, and also to protect sub-surface utilities and pipelines. Matting will also be utilized to protect all terrains as designated by Entergy s Right-Of Way Specialist, Entergy s Policies and Property Owners request. 11. Work performed within the confines of any Entergy Switchyard shall be planned, reviewed and approved by Entergy s on-site designee prior to the start of any project. 12. All Personal Protective Equipment shall be utilized at all times. 13. Fall Protection: 100% Fall Protection is required at all times. 14. All applicable Entergy Construction and Design Standards and Specifications shall be adhered to; all manufacturers installation procedures shall be followed as stated by the manufacturer. Any deviation is not acceptable. 15. Traffic signals shall be utilized and put into place before commencing any construction activities (i.e., law enforcement officers, cones, barricades, men working signs, flagmen, etc.) It is the responsibility of the contractor to adhere to all state, local and regulatory agencies requirements. 14

15 16. Guard Structures of sufficient size and capacity shall be utilized when installing, removing or lifting any conductor or equipment over other utilities, highways, railroads or driveways, etc. 17. All vehicles and heavy equipment shall be operated below minimum designated speeds limits while on all roads, right-of-ways and properties associated with this construction project. If no speed limit is designated than, it is expected that no vehicle or heavy equipment will be operated beyond five (5) miles per hour. 18. Access and egress to all property and facilities shall be properly maintained and secured at all times, before, during, and after all construction activities. 19. Material substitution and alteration is not acceptable without the approval of Entergy s designee. 20. Interpretation of any part herewith in this document can be directed to Entergy s Construction Management Department. 21. All personnel must complete Entergy s Substation Awareness training prior to entering Entergy s property or facilities. 22. All personnel must complete Power Safe training prior to entering Entergy s property or facilities. 23. Daily requirements include the preparation and execution of tailboards and Job Safety Analysis (JSA). 24. A full time Safety Coordinator may be requested or required by Entergy. It will be the contractor s responsibility to supply this qualified personnel. 25. Contractor is required to proactively notify the responsible Operations Center of his presence. The correct TOC or DOC can be obtained from Entergy s Construction Management Department. 26. Contractor is required to proactively notify the responsible agency for all one calls ( Dig Alerts ) for the region in which any work will be performed. Contractor shall also request a face to face appointment with participants of the one call operation in order to ensure that due diligence has been executed. 27. Contractors must obey all railroad crossing laws, remember and communicate this aspect as part of the tailboard and JSA process. All personnel should be reminded periodically through the course of the day. Stop / Look / Listen / Live!!! 15

16 4. COST Entergy requires safety to be the highest priority for all projects. No work shall be carried out without performing a JSA, and have the appropriate JSA form filled out. All safety hazards shall be identified in the JSA. The employee in charge must ensure that the crew performing the work is familiar with the status of the equipment and surrounding area. When working within operating substations, the employee in charge shall identify parts that are energized, establish location and placement of protective grounds, and define the limits of the working space(s) and what switches or breakers disconnect the equipment from the source of supply. Before switching is performed in a substation where work is in progress, the employee performing the switching shall notify all personnel working within the substation. All personnel shall check the status of the structures, lines, and equipment before resuming work. If an employee arrives after switching is completed, the employee in charge shall walk through the work plan to update the late arrival on the job at hand. For work on the existing transmission lines, the contractor employee in charge shall ensure that the crew is familiar with working near energized overhead conductors, performing proper grounding procedures, safety on road crossings, and working in adverse terrain, inside substation, and inside of a plant environment. 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 all applicable overheads but do not include tax gross up. Entergy incurs a tax liability proportional to the amount of customer contributions. Projected Costs including indirect cost through 2014 dollars Description Total Gretna-Harvey 115kV Line $ 6,758 $ 14,118 $ 47,390 $ 100,207 $ 168,473 Nine Mile - South Port 230kV Lines 1 & 2 $ 18,310 $ 121,901 $ 240,396 $ 1,713,837 $ 2,094,443 Total: $ 25,068 $ 136,019 $ 287,786 $ 1,814,044 $ 2,262,916 16

17 5. UPGRADE CLASSIFICATION The ICT has reviewed and determined whether each required upgrade will be considered a Supplemental Upgrade. For more information on cost responsibility for Base Plan and Supplemental Upgrades, see Attachment T to Entergy s OATT. Task Total Cost Base Plan Supplemental FFR Payment Reference Ninemile Southport kV Lines 1& 2 $ 2,094,443 $ 2,094, Gretna Harvey 115kV -- Line $ 168,473 $ 168, Total: $ 2,262, $ 2,262, SCHEDULE A detailed schedule will be prepared subsequent to customer approval to proceed with the project. Based on the Task duration schedules listed below, the overall project in-service date is projected to be January 1, Based on an assumed customer approval date of November 1, 2011, the following are approximate schedule dates: All construction work requiring outages will be performed during acceptable periods of system condition to ensure reliable operation of the system, which most often is the off-peak 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, an evolving system condition may result in cancellation of approved outages by the SOC/TOC and may also result in additional schedule delay. Substation construction will be coordinated with the transmission line outages when possible. Construction resources are available when required. Transmission line and substation projects will begin subsequent to definition phase of the PEP. This schedule does not account for non-typical adverse weather conditions. Schedule durations are high level estimates at this time. A detailed schedule will be prepared upon project approval. Scheduling assumptions and completion dates: Receive customer approval by November 1, Completion of PEP/Estimates by end of March

18 Approval from customer to proceed with the project followed by creation of FP and WOs in place by the end of May Commence engineering, and permitting work in June Order long delivery material by July 2012 for delivery by January 2, Issue design packages to construction by October Secure environmental permits by October Construct substations and line work starting in January 2013, and complete it by the December 31, It is assumed the outages of the bus nodes at 230kV Ninemile and South Port substations are available as per Construction Plans. 7. RISK ASSESSMENT Risk Comment Impact Material costs steel & Equipment Storm-water plan implementation Weather & Equipment Lead Times (Poles) Wetland mitigation Outages may not be available Rising steel, copper, fuel and other market conditions could greatly affect estimated cost. Best guess on SWPPP creation, implementation and monitoring can vary greatly dependant on outcome of environmental study. Unexpected delays on material lead times, unusually inclement weather will impact schedule but might impact AFUDC costs as well. Undetermined until environmental analysis is complete. Preliminary schedule only considers general outage constraints. Specific project schedule may be delayed by days, weeks or months dependant on system conditions. Delays of months = increased project costs. Scope based on design assumptions Varied impact on cost and schedule. *** which may change *-low impact to cost, ** - moderate impact to cost, ***- high impact to cost, **** - very high impact to cost. **** ** ** *** **** 18

19 The following transactions were included in this Facilities Study: 8. CONFIRMED RESERVATIONS Confirmed Reservations OASIS PSE MW Begin End (undesignation) Entergy Services, Inc. (EMO) 1 7/2/1998 7/1/ Entergy Services, Inc. (EMO) 242 3/1/2000 1/1/ Entergy Services, Inc. (EMO) 143 1/1/2001 1/1/ East Texas Electric Cooperative 31 1/1/2001 1/1/ Tennessee Valley Authority 73 9/1/2003 9/1/ (renewal) City Water & Light, Jonesboro 83 1/1/2010 1/1/ (renewal) City Water & Light, Jonesboro 168 1/1/2010 1/1/ Entergy Services, Inc. (EMO) 236 2/1/2003 2/1/ Entergy Services, Inc. (EMO) 91 2/1/2003 2/1/ Entergy Services, Inc. (EMO) 77 2/1/2003 2/1/ Entergy Services, Inc. (EMO) 101 5/1/2004 5/1/ Entergy Services, Inc. (EMO) 20 6/1/2010 6/1/ Entergy Services, Inc. (EMO) 80 8/1/2004 2/1/ Entergy Services, Inc. (EMO) 247 8/1/2004 2/1/ (undesignation) Entergy Services, Inc. (EMO) 1 6/1/2007 6/1/ Entergy Services, Inc. (EMO) 526 1/1/2006 1/1/ (renewal) East Texas Electric Cooperative 75 1/1/2009 1/1/ (renewal) East Texas Electric Cooperative 50 1/1/2009 1/1/ (renewal) East Texas Electric Cooperative 50 1/1/2009 1/1/ Muni Energy Agcy of Miss 40 6/1/2010 6/1/ City of Conway 25 3/1/2010 3/1/ Louisiana Generating LLC 11 3/1/2006 3/1/ CLECO Power LLC (Gen) /1/ /1/ Osceola Light & Power 9 9/1/2009 9/1/ Constellation Energy Commodities Grp. 34 1/1/2006 1/1/ Constellation Energy Commodities Grp. 34 1/1/2006 1/1/ Constellation Energy Commodities Grp. 17 1/1/2006 1/1/ Constellation Energy Commodities Grp. 17 1/1/2006 1/1/ Arkansas Electric Cooperative Corp /1/2007 1/1/ NRG Power Marketing 13 10/1/ /1/ CLECO Power LLC (Gen) 11 4/1/2006 4/1/ Constellation Energy Commodities 60 3/1/2010 3/1/ (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2007 1/1/ East Texas Electric Cooperative 50 3/1/2010 3/1/ Arkansas Electric Cooperative Corp /1/2007 1/1/ Arkansas Electric Cooperative Corp. 84 1/1/2008 1/1/ Arkansas Electric Cooperative Corp /1/2008 1/1/ NRG Power Marketing 320 6/1/2007 6/1/ Entergy Services, Inc. (EMO) 322 6/1/2009 6/1/ CLECO Power Marketing 10 10/1/ /1/ Aquila Networks-MPS 75 3/1/2009 3/1/ Aquila Networks-MPS 75 3/1/2009 3/1/ Aquila Networks-MPS 75 3/1/2009 3/1/ Aquila Networks-MPS 75 3/1/2009 3/1/ Louisiana Energy & Power Authority 3 1/1/2009 1/1/ Louisiana Energy & Power Authority 5 1/1/2009 1/1/ Louisiana Energy & Power Authority 12 1/1/2009 1/1/ East Texas Electric Cooperative 168 1/1/2010 1/1/ Muni Energy Agcy of Miss 20 6/1/2011 6/1/

20 OASIS PSE MW Begin End City of West Memphis 20 1/1/2011 1/1/ East Texas Electric Cooperative 186 1/1/2010 1/1/ (renewal) South Miss Electric Power Assoc. 75 6/1/2009 6/1/ South Miss Electric Power Assoc /1/2010 6/1/ Entergy Services, Inc. (EMO) 10 11/1/ /1/ Entergy Services, Inc. (EMO) 725 1/1/2005 9/1/ Southwestern Electric 78 5/1/2010 5/1/ Constellation Energy Commodities Grp. 30 4/1/2012 4/1/ City of Conway 50 4/1/2012 4/1/ Entergy Services, Inc. (EMO) 300 1/1/2008 1/1/ (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2008 1/1/ (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2008 1/1/ Arkansas Electric Cooperative Corp /1/2008 1/1/ East Texas Electric Cooperative 29 1/1/2008 1/1/ East Texas Electric Cooperative 35 1/1/2008 1/1/ (undesignation) East Texas Electric Cooperative 1 1/1/2008 1/1/ (renewal) NRG Power Marketing 103 1/1/2011 1/1/ (renewal) NRG Power Marketing 3 7/1/2009 7/1/ Westar Energy 6 10/1/ /1/ Empire District Electric 50 3/1/2010 3/1/ Empire District Electric 50 3/1/2010 3/1/ (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2011 1/1/ (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2009 1/1/ (undesignation) East Texas Electric Cooperative 1 1/1/2010 1/1/ Entergy Services, Inc. (EMO) 158 1/1/2010 1/1/ (undesignation) Entergy Services, Inc. (EMO) 1 7/1/2009 7/1/ Entergy Services, Inc. (EMO) 520 7/1/2009 7/1/ (undesignation) East Texas Electric Cooperative 1 1/1/2009 1/1/ (renewal) Louisiana Energy & Power Authority 6 4/1/2009 4/1/ (renewal) NRG Power Marketing 5 9/1/2009 9/1/ NRG Power Marketing 300 1/1/2008 1/1/ (renewal) City of Prescott 22 4/1/2009 4/1/ (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2009 1/1/ (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2009 1/1/ (renewal) NRG Power Marketing 103 7/1/2010 7/1/ Entergy Services, Inc. (EMO) 206 6/1/2012 6/1/ (renewal) Morgan Stanley Commodities Group 102 1/1/2009 1/1/ (renewal) Morgan Stanley Commodities Group 102 1/1/2009 1/1/ Constellation 5 1/1/2010 1/1/ NRG Power Marketing 5 7/1/2010 7/1/ (renewal) MidAmerican Energy, Inc. 50 1/1/2009 1/1/ MidAmerican Energy, Inc. 50 1/1/2009 1/1/ MidAmerican Energy, Inc. 50 1/1/2009 1/1/ MidAmerican Energy, Inc. 50 1/1/2009 1/1/ MidAmerican Energy, Inc. 7 3/1/2009 3/1/ NRG Power Marketing 40 1/1/2010 1/1/ Merrill Lynch Commodities 1 4/1/2009 4/1/ Merrill Lynch Commodities 25 4/1/2009 4/1/ NRG Power Marketing 20 1/1/2010 1/1/ NRG Power Marketing 20 1/1/2010 1/1/ NRG Power Marketing 20 1/1/2010 1/1/ Entergy Services, Inc. (EMO) 587 3/1/2009 1/1/ Entergy Services, Inc. (EMO) 103 3/1/2009 1/1/ Entergy Services, Inc. (EMO) 32 3/1/2009 1/1/ Entergy Services, Inc. (EMO) 122 3/1/2009 1/1/

21 OASIS PSE MW Begin End Entergy Services, Inc. (EMO) 134 3/1/2009 1/1/ CLECO Power Marketing 58 5/1/2001 1/1/ CLECO Power Marketing 32 5/1/2001 1/1/ (renewal) NRG Power Marketing 300 1/1/2010 1/1/ (renewal) NRG Power Marketing 100 9/1/2010 9/1/ CLECO Power Marketing 9 4/1/2009 5/1/ NRG Power Marketing 83 1/1/2010 1/1/ CLECO Power Marketing 41 5/1/2009 5/1/ (undesignation) Entergy Services, Inc. (EMO) 1 6/1/2010 6/1/ Entergy Services, Inc. (EMO) 100 6/1/2010 6/1/ (undesignation) Entergy Services (SPO) 1 6/1/2010 6/1/ Entergy Services (SPO) 485 6/1/2010 6/1/ Missouri Joint Municipal 6 10/1/ /1/ (undesignation) Entergy Services (SPO) 1 6/1/2012 6/1/ SMEPA 21 6/1/2012 6/1/ NRG Power Marketing 25 1/1/2011 1/1/ (renewal) Merrill Lynch Commodities 60 11/1/ /1/ Merrill Lynch Commodities 15 1/1/2011 1/1/ (renewal) Merrill Lynch Commodities 16 11/1/ /1/ (renewal) Merrill Lynch Commodities 4 11/1/ /1/ Ameren Energy, Inc. 75 9/1/2009 9/1/ Entergy Services (SPO) 600 1/1/2013 1/1/ (renewal) Cargill Power Markets, LLC 103 1/1/2011 1/1/ (renewal) Cargill Power Markets, LLC 103 1/1/2011 1/1/ NRG Power Marketing 100 1/1/2011 1/1/ NRG Power Marketing 100 1/1/2011 1/1/ (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2013 1/1/ (renewal) NRG Power Marketing 100 1/1/2011 1/1/ (renewal) NRG Power Marketing 100 1/1/2011 1/1/ (renewal) NRG Power Marketing 206 1/1/2011 1/1/ (renewal) Muni Energy Agcy of Miss 19 1/1/2010 1/1/ Missouri Joint Municipal 3 9/1/2009 9/1/ NRG Power Marketing 25 1/1/2011 1/1/ Entergy Services (SPO) 15 5/1/2010 5/1/ Entergy Services (SPO) 30 5/1/2010 5/1/ Hope Water & Light 10 10/1/ /1/ South Miss Electric Power Assoc /1/ /1/ (renewal) American Electric Power 45 1/1/2011 1/1/ (renewal) American Electric Power 6 1/1/2011 1/1/ NRG Power Marketing 13 1/1/2012 1/1/ NRG Power Marketing 50 5/1/2010 5/1/ Arkansas Electric Cooperative Corp /1/2010 1/1/ Arkansas Electric Cooperative Corp /1/2010 1/1/ (renewal) Entergy Services, Inc. (EMO) 150 5/1/2010 5/1/ (renewal) Entergy Services, Inc. (EMO) 135 5/1/2010 5/1/ Arkansas Electric Cooperative Corp. 84 1/1/2010 1/1/ MOWR 5 3/1/2010 3/1/ (renewal) Muni Energy Agcy of Miss 13 6/1/2010 6/1/ Cargill Power Markets, LLC 40 1/1/2012 1/1/ South Miss Electric Power Assoc /1/2010 5/1/ South Miss Electric Power Assoc /1/2010 6/1/ South Miss Electric Power Assoc /1/2010 5/1/ NRG Power Marketing 100 1/1/2011 1/1/ NRG Power Marketing 100 1/1/2011 1/1/ NRG Power Marketing 22 1/1/2011 1/1/

22 OASIS PSE MW Begin End NRG Power Marketing 28 1/1/2011 1/1/ NRG Power Marketing 42 8/1/2006 8/1/ NRG Power Marketing 60 3/1/2010 3/1/ NRG Power Marketing 60 4/1/2012 4/1/ WRGS 15 4/1/2012 4/1/ (undesignation) Entergy Services, Inc. (EMO) 1 8/1/2012 1/1/ NRG Power Marketing 75 6/1/2012 6/1/ NRG Power Marketing 100 6/1/2012 6/1/ NRG Power Marketing 100 6/1/2012 6/1/ NRG Power Marketing 10 1/1/2014 1/1/ NRG Power Marketing 10 1/1/2013 1/1/ NRG Power Marketing 103 1/1/2011 1/1/ NRG Power Marketing 206 6/1/2012 6/1/ NRG Power Marketing 50 1/1/2013 1/1/ NRG Power Marketing 10 7/1/2010 7/1/ Entergy Services, Inc. (EMO) 20 6/1/2013 6/1/ Entergy Services, Inc. (EMO) 101 6/1/2013 6/1/ NRG Power Marketing 60 1/1/2013 1/1/ Entergy Services, Inc. (EMO) 804 5/1/2013 5/1/ (renewal) NRG Power Marketing 300 1/1/2013 1/1/ (renewal) NRG Power Marketing 300 1/1/2015 1/1/ (renewal) CLECO Power LLC (Gen) 35 1/1/2011 1/1/ AECI / APM 103 1/1/2012 1/1/ (renewal) NRG Power Marketing 8 3/1/2011 3/1/ (undesignation) Entergy Services, Inc. (EMO) 1 2/1/2012 2/1/ Entergy Services, Inc. (EMO) 100 2/1/2012 2/1/ (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2013 1/1/ (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2012 1/1/

23 9. PRE-888 TRANSACTIONS OASIS PSE MW Begin End East Texas Electric Cooperative 55 1/1/2006 1/1/ Entergy Services, Inc. (EMO) /1/2007 1/1/ Entergy Services, Inc. (EMO) 741 1/1/2007 1/1/ Entergy Services, Inc. (EMO) /1/2007 1/1/ Entergy Services, Inc. (EMO) /1/2007 1/1/ Entergy Services, Inc. (EMO) 59 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 148 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 194 1/1/2007 1/1/ Entergy Services, Inc. (EMO) /1/2007 1/1/ Entergy Services, Inc. (EMO) /1/2007 1/1/ Entergy Services, Inc. (EMO) 683 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 140 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 456 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 739 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 183 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 64 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 870 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 129 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 140 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 130 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 65 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 947 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 61 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 304 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 351 1/1/2007 1/1/ Entergy Services, Inc. (EMO) 692 1/1/2007 1/1/ Entergy Services, Inc. (EMO) /1/2007 1/1/ Entergy Services, Inc. (EMO) 433 1/1/2007 1/1/ Entergy Services, Inc. (EMO) /1/2007 1/1/ Entergy Services, Inc. (EMO) 946 1/1/2007 1/1/ Entergy Services, Inc. (EMO) /1/2007 1/1/ Entergy Services, Inc. (EMO) 75 8/1/2007 1/1/ Entergy Services, Inc. (EMO) 86 8/1/2007 1/1/ Entergy Services, Inc. (EMO) 68 8/1/2007 1/1/ Entergy Services, Inc. (EMO) 78 8/1/2007 1/1/ Entergy Services, Inc. (EMO) 11 8/1/2007 1/1/ Entergy Services, Inc. (EMO) 69 8/1/2007 1/1/ Entergy Services, Inc. (EMO) 14 8/1/2007 1/1/

24 10. STUDY QUEUE OASIS PSE MW Begin End NRG Power Marketing 300 1/1/2013 1/1/ NRG Power Marketing 300 1/1/2013 1/1/ Brazos Electric Cooperative 100 1/1/2012 1/1/ Brazos Electric Cooperative 100 1/1/2012 1/1/ Brazos Electric Cooperative 100 1/1/2012 1/1/ Brazos Electric Cooperative 100 1/1/2012 1/1/ Brazos Electric Cooperative 100 1/1/2012 1/1/ undesignation Entergy Services (SPO) 1 1/1/2012 1/1/ Cargill Power Markets 101 7/1/2012 7/1/ Cargill Power Markets 101 7/1/2012 7/1/ Cargill Power Markets 101 7/1/2012 7/1/ Cargill Power Markets 101 7/1/2013 7/1/ Cargill Power Markets 101 7/1/2013 7/1/ Cargill Power Markets 101 7/1/2013 7/1/ AEPM 65 1/1/2015 1/1/ Entergy Services (SPO) 322 2/1/2011 2/1/

25 11. ATTACHMENTS 11.1 Table of Acronyms ACSR ACSS AFUDC ATC CCN EES EHV ICT JSA kv MCM MVA MW NPDES OASIS OATT OG&E PEP POR SES SOC SHV SW TOCSWEPCO TOC USACE Aluminum Conductor Steel Reinforced Aluminum Conductor Steel Supported Allowance for Funds Used During Construction Available Transfer Capability Certificate of Convenience and Necessity Entergy Control Area Extra-High Voltage Independent Coordinator of Transmission Job Safety Analysis Kilo-Volt (M) Thousand Circular Mils Mega-Volt Amp Mega-Watt National Pollution Discharge Elimination System Online Access and Same-time Information System Open Access Transmission Tariff Oklahoma Gas & Electric Project Execution Plan Point of Receipt Steam Electric Station System Operations Center Super High Voltage Switch Station Transmission Operations Center Southwest Electric Power Company Transmission Operations Center United States of America Corp of Engineers 25

26 11.2 Drawings Location Description Ninemile 230kV Substation Drawing Number L0080S02 Ninemile 230kV Substation L0080S03 Southport 230kV Substation L0055S01 Gretna 115kV Substation L0659S01 26

27 27

28 28

29 29

30 30

31 11.3 Duration Schedule 31

32 32