West Memphis Facilty Study for Trasmission Service

TRANSMISSION LINE & SUBSTATION PROJECTS

COMPANY: ENTERGY SERVICES, INC.

CUSTOMER: ENTERGY SERVICES, INC. (SPO)

FACILITIES STUDY

EJO NO. F4PPAR0490

ICTT-2010-158

TRANSMISSION SERVICE FACILITIES STUDY

OASIS 75009407

Revision: 0

Rev Issue Date

Description of Revision Prepared

By Approved

By

B 7/14/11 Submitted to TPD, JET, for review/comments

RP AH

C 7/15/11 Approved with Revisions per comments from JET,TPD, and Director

RP AH

D 7/18/11 Formatted by TPD GWR

E 7/22/11 Update Schedule Data GWR

0 7/27/11 ICT Determines Upgrade Classification Sherri Maxey

Ben Roubique

OASIS 75009407 Entergy Services, Inc. (SPO) Facilities Study

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TABLE OF CONTENTS

1. PROJECT SUMMARY 3 1.1 Background and Project Need 3 1.2 Scope Summary 3 1.3 Cost Summary 5 1.4 Schedule Summary 5

2. SAFETY REQUIREMENTS 5

3. GENERAL ASSUMPTIONS 5

4. GENERAL SCOPE OF WORK 6 4.1 Ebony 161 kV Switching Station: Add a 24 MVAR Capacitor Bank 6 4.2 Ebony 161 kV Switching Station: Upgrade the 24 MVAR Capacitor Bank to 36 MVARs 8 4.3 Moses 161 kV Substation: Add 12 MVAR Capacitor Bank 8

5. COST 10

6. UPGRADE CLASSIFICATION 10

7. SCHEDULE 10

8. RISK ASSESSMENT 12

9. CONFIRMED RESERVATIONS 13

10. PRE-888 TRANSACTIONS 18

11. STUDY QUEUE 19

12. ATTACHMENTS 20 12.1 Table of Acronyms 20 12.2 Drawings 21 12.3 Duration Schedule 21


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1. PROJECT SUMMARY

1.1 Background and Project Need The purpose of this Facilities Study is to determine the availability of undesignation of 140 MW of yearly network transmission service on Entergy’s transmission system from 1/1/2012 to 1/1/2042. This study was performed on the latest available January 2012 – October 2012 monthly models, 2012–2020 winter, and 2013–2020 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 Facilities Study has identified some transmission constraints. The following projects are needed prior to the start of transmission service.

1.2.1 2011-2013 Approved Entergy Construction Plan Projects required by

1/1/2014 The following projects are approved in the 2011-2013 Entergy Construction Plan. These projects are required to be in-service prior to January 1, 2014:

Jonesboro - Hergett 161 kV line upgrade – 2012 Expected ISD.

1.2.2 Ebony 161 kV Switching Station: Add a 24 MVAR capacitor bank For this TSR, the following upgrade is required to be in-service by January 1, 2013:

For the loss of the West Memphis EHV 500/161 kV autotransformer, voltages at the following substations decrease below 0.92pu:

West Memphis EHV 161 kV

Ebony Switching Station 161 kV

Marion 161 kV

Hughes 161 kV

Kuhn Road 161 kV

Harrisburg Switching Station 161 kV

Lepanto 161 kV

Marked Tree 161 kV

Harrisburg 161 kV

Wynne Industrial 161 kV

Wynne South 161 kV


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Trumann 161 kV

Wynne East 161 kV

Twist 161 kV

It is required that the 24 MVAR capacitor bank at Ebony 161 kV Switching Station be upgraded to 36 MVARs.

1.2.3 Ebony 161 kV Switching Station: Upgrade the 24 MVAR capacitor bank to

36 MVARs For this TSR, the following upgrade is required to be in-service by January 1, 2013. For the loss of the West Memphis EHV 500/161 kV autotransformer, voltages at the following substations decrease below 0.92pu.



Marion 161 kV

Hughes 161 kV

Kuhn Road 161 kV


Lepanto 161 kV

Marked Tree 161 kV

Harrisburg 161 kV


Wynne South 161 kV

Trumann 161 kV

Wynne East 161 kV

Twist 161 kV

1.2.4 Moses 161 kV Substation: Add 12 MVAR Capacitor Bank For this TSR, the following upgrade is required to be in-service by January 1, 2013.

For the loss of the West Memphis EHV 500/161 kV autotransformer, voltages at the following substations decrease below 0.92pu:



Marion 161 kV

Hughes 161 kV

Kuhn Road 161 kV


Lepanto 161 kV


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Marked Tree 161 kV

Harrisburg 161 kV


Wynne South 161 kV

Trumann 161 kV

Wynne East 161 kV

Twist 161 kV

It is required that a 12 MVAR capacitor bank be installed at the Moses 161 kV substation.

1.3 Cost Summary

The estimated total project cost in 2011 dollars is $1,565,000. This does not include Tax Gross Up, which may apply (rate at this time is 27.16%).

The ICT has assigned $809,838 as Base Case upgrades, and $755,218 as Supplemental Upgrade based on Attachment T of Entergy’s OATT.

1.4 Schedule Summary

The requested in-service date is January 1, 2012. The duration of work scoped and estimated below is 14 months, starting from October 1, 2011, and is expected to be completed by December 31, 2012. Transmission service is projected to be available January 1, 2013, based on in-service of all required projects.

2. 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 schedule described below. The use of 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.


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All costs above represent good faith estimates in today’s dollars, 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. GENERAL SCOPE OF WORK

4.1 Ebony 161 kV Switching Station: Add a 24 MVAR Capacitor Bank Site Work

Install, fill and grade new area to prepare site for new capacitor bank.

Install 90 tons of crushed rock in the expanded fence area.

Install 45 tons of crushed rock after conduit and ground grid installation.

Foundation Work

Install three (3) 161 kv CCVT foundations (drilled piers).

Install foundation for one (1) 161 kv cap-switcher (Two (2) drilled piers).

Install foundation for one (1) 90’ lightning mast.

Install foundation for one (1) 161 kv, 24 MVAR capacitor bank (three (3) sets of two (2) pads).

Install one (1) pull box for conduit bank installation.

Install 500’ of conduit.

Install 300’ of ground grid.

Electrical Work

Install one (1) 161 kV 2000A disconnect vertical switch w/125VDC motor operator.

Install one (1) 161 kV 1200A existing disconnect vertical line switch with vacuum bottle, with 125 VDC motor operator to be used as a disconnect switch for the capacitor bank.

Install one (1) 161 kV, 24.0 MVAR cap bank, including steel structure.

Install one (1) 90’ lightning mast steel structure.

Install one (1) 161 kV cap-switcher with 150 ohm resistors.

Install three (3) CCVT pedestals.

Install nine (9) 161 kV porcelain post Insulator.

Install 200LF 336 MCM conductor and associated fittings.


Install above-ground “pigtails” to equipment and structures.

Install above-ground conduits to equipment.

Relay Work

Add an AC/DC split panel per Entergy standard PM0101 option C.

Add D20 RTU.


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Purchase and install 24” capacitor bank panel with SEL-451. An Entergy representative should also participate in conducting the training along with the SEL representative.

Purchase one (1) line trap on A Phase to block a 165 kHz carrier signal. Specifications include 400 amp and vertical pedestal mount.

Purchase, design and install three (3) CCVTs to monitor the bus voltage.

Purchase, design and install a resistive potential device on the capacitor bank neutral.

Purchase and install outdoor neutral NEMA Type 4X high voltage CCVT junction box.

Purchase and install outdoor NEMA Type 4X neutral potential junction box.

Purchase and install approximately 12 cables from the control house to the yard devices, including capacitor switcher, bus CCVT junction box, and neutral potential junction box.

RTU configuration will be required.

Relay settings will be required. Relay design and relay settings need to work closely together to ensure proper coordination between the capacitor bank protection and the line reclosing. For example, ensure the proper settings on the cap bank protection trips on the cap switcher when there is a fault on the line. The bank trip needs to be completed prior to the reclosing at the remote line ends.

Host database changes will be required.

Settings Work

Calculate and develop relay setting for the new SEL-451 capacitor bank relays.

Revise RTU configuration.

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. Construction will be accomplished by pre-qualified electrical contractor crews under the supervision of Entergy personnel.


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4.2 Ebony 161 kV Switching Station: Upgrade the 24 MVAR Capacitor Bank to 36 MVARs

This upgrade provides for an additional 12 MVARs to the Ebony 161 kV Switching Station project referenced in the approved capital projects for 2011 – 2012 budget years. The upgrade from 24 MVARs to 36 MVARs would require an upgrade to the capacitor bank electrical equipment only. The site, foundation, and electrical support steel would be sufficient. There would also be some relaying and relay settings calculation modifications to be made due to the increase in the size of the capacitor bank.

4.3 Moses 161 kV Substation: Add 12 MVAR Capacitor Bank

For this TSR, the following upgrade is required to be in-service by January 1, 2013.

Site Work

Install, fill and grade new area to prepare site for new capacitor bank.

Install 90 tons of crushed rock in the expanded fence area.

Install 45 tons of crushed rock after conduit & ground grid installation.

Foundation Work

Install 3-161 kV CCVT foundations (drilled piers).

Install foundation for one (1) 161 kV cap-switcher (two (2) drilled piers).

Install foundation for one (1) 90’ lightning mast.

Install foundation for one (1) 161 kV, 12 MVAR capacitor bank (three (3) sets of two (2) pads).

Install one (1) pull box for conduit bank installation.

Install 500’ of conduit.

Install 300’ of ground grid.

Electrical Work

Install one (1) 161 kV 2000A disconnect vertical switch with 125 VDC motor operator.

Install one (1) 161 kV 1200A existing disconnect vertical line switch with vacuum bottle with 125 VDC motor operator to be used as a disconnect switch for the capacitor bank.

Install one (1) 161 kV, 12.0 MVAR cap bank, including steel structure.

Install one (1) 90’ lightning mast steel structure.

Install one (1) 161 kV cap-switcher with 150 ohm resistors.

Install three (3) CCVT pedestals.

Install nine (9) 161 kV porcelain post Insulator.



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Install above-ground “pigtails” to equipment and structures.

Install above-ground conduits to equipment.

Relay Work

Add an AC/DC split panel per Entergy standard PM0101 option C.

Add D20 RTU.

Purchase and install 24” capacitor bank panel with SEL-451. An Entergy representative should also participate in conducting the training, along with the SEL representative.

Purchase one (1) line trap on A Phase to block a 165 kHz carrier signal. Specifications include 400 amp and vertical pedestal mount.

Purchase, design and install three (3) CCVTs to monitor the bus voltage.

Purchase, design and install a resistive potential device on the capacitor bank neutral.

Purchase and install outdoor neutral NEMA type 4X high voltage CCVT junction box.

Purchase and install outdoor NEMA type 4X neutral potential junction box.

Purchase and install approximately 12 cables from the control house to the yard devices, including capacitor switcher, bus CCVT junction box, and neutral potential junction box.

RTU Configuration will be required.

Relay settings will be required. Relay design and relay settings need to work closely together to ensure proper coordination between the capacitor bank protection and the line reclosing. For example, ensure the proper settings on the cap bank protection trips the cap switcher when there is a fault on the line. The bank trip needs to be completed prior to the reclosing at the remote line ends.

Host database changes will be required.

Settings Work

Calculate and develop relay setting for the new SEL-451 capacitor bank relays.

Revise RTU configuration.

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.


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Construction will be accomplished by pre-qualified electrical contractor crews under the supervision of Entergy personnel.

5. COST

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 are through 2011 dollars

6. 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 FFRs Reference

Ebony 24 MVAR $ 809,838 $ 809,838 Section 4.1

Ebony 24 to 36 MVAR $ 48,028 $ 48,028 Section 4.2

Moses 12 MVAR $ 707,190 $ 707,190 Section 4.3

TOTAL COST: $ 1,565,056 $ 809,838 $ 755,218

7. 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, 2013. Based on an assumed customer approval date of October 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-

Project Title 2011 2012 Total

Ebony 161kV Switching Station - Install 24MVAR

Capacitor Bank 113,091$ 696,747$ 809,838$ Ebony 161kV Switching Station - Upgrade

24MVAR Capacitor Bank to 36MVAR's 259$ 47,769$ 48,028$ Moses 161 kV Substation: Add 12 MVAR

Capacitor Bank 101,337$ 605,853$ 707,190$ Total Project Cost: 214,687$ 1,350,369$ 1,565,056$


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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 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 October 1, 2011.

Completion of PEP/estimates by December 1, 2011.

Approval from customer to proceed with the project followed by creation of FP and work orders in place by January 1, 2012.

Commence engineering and permitting work by February 1, 2012.

Issue design packages to construction by June 1, 2012.

Construction work starting August 1, 2012, and complete by December 31, 2012.

It is assumed the outages are available as per Construction Plans.

The customer requested in-service date of January 1, 2012, is not attainable based on the duration assumptions made in this study.


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8. RISK ASSESSMENT

Risk Comment Impact

Material costs steel & Equipment

Rising steel, copper, fuel and other market conditions could greatly affect estimated cost.

**

Storm-water plan implementation

Best guess on SWPPP creation, implementation and monitoring can vary greatly dependant on outcome of environmental study.

*

Weather & Equipment Lead Times

Unexpected delays on material lead times, unusually inclement weather will impact schedule but might impact AFUDC costs as well.

**

Wetland mitigation Undetermined until environmental analysis is complete.

*

Outages may not be available

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 which may change Varied impact on cost and schedule.

****

*-low impact to cost, ** - moderate impact to cost, ***- high impact to cost, **** - very high impact to cost.


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9. CONFIRMED RESERVATIONS

The following transactions were included in this Facilities Study:

OASIS PSE MW Begin End

569011 Entergy Services, Inc. (EMO) 242 3/1/2000 1/1/2014


759294 East Texas Electric Cooperative 31 1/1/2001 1/1/2018

1096986 Tennessee Valley Authority 73 9/1/2003 9/1/2013

1099991 (renewal) City Water & Light, Jonesboro 83 1/1/2010 1/1/2016

1099997 (renewal) City Water & Light, Jonesboro 168 1/1/2010 1/1/2016








1289686 (undesignation) Entergy Services, Inc. (EMO) 1 6/1/2007 6/1/2030


1309874 (renewal) East Texas Electric Cooperative 75 1/1/2009 1/1/2017



1356328 Muni Energy Agcy of Miss 40 6/1/2010 6/1/2040

1373643 City of Conway 25 3/1/2010 3/1/2040

1375299 Louisiana Generating LLC 11 3/1/2006 3/1/2013

1375559 CLECO Power LLC (Gen) 675 12/1/2006 12/1/2016

1380484 Osceola Light & Power 9 9/1/2009 9/1/2039

1381398 Constellation Energy Commodities Grp.

34 1/1/2006 1/1/2036


34 1/1/2006 1/1/2036


17 1/1/2006 1/1/2036


17 1/1/2006 1/1/2036

1383852 Arkansas Electric Cooperative Corp. 550 1/1/2007 1/1/2017

1385158 NRG Power Marketing 13 10/1/20070 10/1/2027

1387272 CLECO Power LLC (Gen) 11 4/1/2006 4/1/2016

1410022 Constellation Energy Commodities 60 3/1/2010 3/1/2040








1456636 CLECO Power Marketing 10 10/1/2007 10/1/2012

1460876 Aquila Networks-MPS 75 3/1/2009 3/1/2029



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1460898 Louisiana Energy & Power Authority 3 1/1/2009 1/1/2030




1468113 Muni Energy Agcy of Miss 20 6/1/2011 6/1/2041

1470484 City of West Memphis 20 1/1/2011 1/1/2041




1495910 Southwestern Electric 78 5/1/2010 5/1/2013


30 4/1/2012 4/1/2042

1498129 City of Conway 50 4/1/2012 4/1/2042







1514105 (undesignation) East Texas Electric Cooperative 1 1/1/2008 1/1/2017

1517005 (renewal) NRG Power Marketing 103 1/1/2011 1/1/2026


1527816 Westar Energy 6 10/1/2007 10/1/2012

1530287 Empire District Electric 50 3/1/2010 3/1/2030

1530288 Empire District Electric 50 3/1/2010 3/1/2030








1564001 (renewal) Louisiana Energy & Power Authority 6 4/1/2009 4/1/2014



1585225 (renewal) City of Prescott 22 4/1/2009 4/1/2039





1598885 (renewal) Morgan Stanley Commodities Group 102 1/1/2009 1/1/2014

1598886 (renewal) Morgan Stanley Commodities Group 102 1/1/2009 1/1/2014

1601111 Constellation 5 1/1/2010 1/1/2015


1615102 (renewal) MidAmerican Energy, Inc. 50 1/1/2009 1/1/2014

1615103 MidAmerican Energy, Inc. 50 1/1/2009 1/1/2014


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1632265 Merrill Lynch Commodities 1 4/1/2009 4/1/2014



















1648591 (undesignation) Entergy Services (SPO) 1 6/1/2010 6/1/2012

1648592 Entergy Services (SPO) 485 6/1/2010 6/1/2012

1655366 Missouri Joint Municipal 6 10/1/2009 10/1/2014


1658088 SMEPA 21 6/1/2012 6/1/2042


1665168 (renewal) Merrill Lynch Commodities 60 11/1/2009 11/1/2014




1665899 Ameren Energy, Inc. 75 9/1/2009 9/1/2014


1669126 (renewal) Cargill Power Markets, LLC 103 1/1/2011 1/1/2016

1669127 (renewal) Cargill Power Markets, LLC 103 1/1/2011 1/1/2016







1685869 (renewal) Muni Energy Agcy of Miss 19 1/1/2010 1/1/2018

1689499 Missouri Joint Municipal 3 9/1/2009 9/1/2014





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73454527 Hope Water & Light 10 10/1/2009 10/1/2032

73457918 South Miss Electric Power Assoc. 180 10/1/2009 10/1/2014

73573797 (renewal) American Electric Power 45 1/1/2011 1/1/2029

73586299 (renewal) American Electric Power 6 1/1/2011 1/1/2029




73741113 (renewal) Entergy Services, Inc. (EMO) 150 5/1/2010 5/1/2020



73820650 MOWR 5 3/1/2010 3/1/2040

73942862 (renewal) Muni Energy Agcy of Miss 13 6/1/2010 6/1/2015

73970673 Cargill Power Markets, LLC 40 1/1/2012 1/1/2016











74233619 WRGS 15 4/1/2012 4/1/2017














74728369 Brazos Electric Cooperative 100 1/1/2012 1/1/2017








74829975 (renewal) CLECO Power LLC (Gen) 35 1/1/2011 1/1/2016

74835023 AECI / APM 103 1/1/2012 1/1/2017



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10. PRE-888 TRANSACTIONS









































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11. STUDY QUEUE





74799834 Cargill Power Markets 101 7/1/2012 7/1/2017






74846159 AEPM 65 1/1/2015 1/1/2020














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12. ATTACHMENTS

12.1 Table of Acronyms

A Amperes

AC/DC Alternating Current / Direct Current

ACSR Aluminum Conductor Steel Reinforced

ACSS Aluminum Conductor Steel Supported

AFUDC Allowance for Funds Used During Construction

ATC Available Transfer Capability

CCN Certificate of Convenience and Necessity

CCVT Coupling Capacitor Voltage Transformer

EES Entergy Control Area

EHV Extra-High Voltage

FP Funded Project

ICT Independent Coordinator of Transmission

ISD In-Service Date

kV Kilo-Volt

LF Linear Feet

MCM (M) Thousand Circular Mils

MUST Managing and Utilizing System Transmission

MVA Mega-Volt Ampere

MVAR Mega Volt Ampere Reactive

MW Mega-Watt

NEMA National Electrical Manufacturers Association

NPDES National Pollution Discharge Elimination System

OASIS Online Access and Same-time Information System

OATT Open Access Transmission Tariff

OG&E Oklahoma Gas & Electric

PEP Project Execution Plan

PM&C Project Management & Construction

P&P Plan & Profile (drawing)

POR Point of Receipt

PSS/E Power System Simulation Program

PTI Power Technologies Incorporated

ROW Right of Way

RTU Remote Terminal Unit

SEL Schweitzer Engineering Labs

SES Steam Electric Station

SMEPA South Mississippi Electric Power Association

SOC System Operations Center

SHV Super High Voltage

SW Switch Station

SWEPCO Southwest Electric Power Company

SWPPP Storm Water Pollution Prevention Plan

TOC Transmission Operations Center

TSR Transmission Service Request

TVA Tennessee Valley Authority

USACE United States of America Corps of Engineers

VDC Voltage Direct Current

WOs Work Orders


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12.2 Drawings

Description Drawing Number Page

Ebony Switch Station A4317SO1 22

Moses SES Substation A2206SO1 23

Ebony Substation One Line Substation Upgrades 24

Moses Substation One Line Substation Upgrades 25

12.3 Duration Schedule

Description Page

Preliminary Schedule 26

12 MVAR BXXXX

BXXXX150

Base PlanAdd 24 MVARCapacitor Bank

G

SupplementalAdditional 12

MVARCapacitor Bank

12 MVARBXXXX

BXXXX150

G

Add 12 MVARCapacitor Bank

G

Ebony Switch Station Locatiton

Add 24 & 12 MVAR Capacitor Bank

Moses SESLocation

Add 12 MVAR CapacitorBank

OASIS 75009407EJO F4PPAR0490

OASIS # 75009407 EJO F4PPAR0490 Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

JET Meeting - Facility Study Review

PM with Project Team Input Develops OASIS Study documents

Entergy receives customer approval

Entergy completes PEP/Estimates

Approval from customer to proceed with the project followed by creation of FP and WOs

Commence engineering, and permitting work

Issue design packages to construction

Construction work in Ebony 161kV Switching Station and Moses 161kV Substation

It is assumed the outages are available as per Construction plans

Projected In-Service Date

2011 2012

Target ISD 12-31-2012

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West Memphis Facilty Study for Trasmission Service

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