transmission service faciltiy study: oasis 1547988o install 120klbs of 666mcm acsr flamingo...

TRANSMISSION LINE & SUBSTATION PROJECTS

COMPANY: EAI

CUSTOMER: WESTAR ENERGY GEN & MKTG

FACILITIY STUDY EJO # F4PPAR0447

ICTT-2008-023

TRANSMISSION SERVICE FACILTIY STUDY: OASIS 1547988

Revision: 1

Rev Issue Date Description of Revision Prepared

By Approved

By F 7/11/08 REV F Input Tables FWM

0 7/14/08 Final Draft issued to ICT GWR

1 7/21/08 ICT Determines Upgrade Classification James Lyle Jody Holland

WESTAR ENERGY GEN & MKTG OASIS 1547988 Facility Study

TABLE OF CONTENTS

1. PROJECT SUMMARY ........................................................................4 1.1 Background and Project Need ................................................................................. 4 1.2 Scope Summary....................................................................................................... 4

A. Norfork-Calico Rock 161kV Transmission Line – Upgrade to 170 MVA....... 4 B. Calico Rock-Melbourne 161kV Transmission Line – Upgrade to 170 MVA.. 4 C. Melbourne-Sage 161kV Transmission Line – Upgrade to 180 MVA ............ 4 D. Monette-Paragould 161kV Transmission Line – Upgrade to 170 MVA ........ 4 E. Russellville South 161kV and Dardanelle Dam 161kV Substations ............. 5 F. Russellville South 161kV Substation ............................................................ 5 G. Russellville East-Russellville North 161kV Transmission Line – Upgrade to

400 MVA...................................................................................................... 5 H. ANO-Russellville North 161kV Transmission Line - Upgrade to 449 MVA ... 5 I. Danville-North Magazine REA 161kV Transmission Line – Upgrade to 176

MVA............................................................................................................. 6 1.3 Cost Summary.......................................................................................................... 6 1.4 Schedule Summary .................................................................................................. 6

2. SAFETY AWARENESS ......................................................................6

3. GENERAL ASSUMPTIONS................................................................7

4. SCOPE OF WORK..............................................................................7 4.1 Norfork-Calico Rock 161kV Transmission Line – Upgrade to 170 MVA................ 7 4.2 Calico Rock-Melbourne 161kV Transmission Line – Upgrade to 170 MVA........... 8 4.3 Melbourne-Sage 161kV Transmission Line – Upgrade to 180 MVA ..................... 9 4.4 Monette-Paragould 161kV Transmission Line – Upgrade to 170 MVA ............... 10 4.5 Russellville South 161kV Substations - Upgrade Dardanelle Dam Line Terminals

............................................................................................................................ 11 4.6 Paragould 161kV Substation – Upgrade Line Terminal Equipment..................... 11 4.7 Melbourne 161kV Substation – Upgrade Switch Jumpers .................................. 11 4.8 Dardanelle Dam 161kV Substation (SPA) – Upgrade Russellville South line

Terminal .............................................................................................................. 12 4.9 Russellville South 161kV Substation - Upgrade Russellville East Line Terminal. 12 4.10 Russellville East – Russellville North 161kV Transmission Line – Upgrade to

400MVA .............................................................................................................. 12 4.11 Arkansas Nuclear One 161kV Substation – Upgrade Russellville North Line

Terminal .............................................................................................................. 13 4.12 Russellville North 161kV Substation – Upgrade ANO Line Terminal................... 14 4.13 ANO-Russellville North 161kV Transmission Line - Upgrade to 449 MVA .......... 14 4.14 Danville 161kV Substation – Upgrade N. Magazine Line Equipment .................. 15 4.15 Danville-North Magazine REA 161kV Transmission Line – Upgrade to 176 MVA

............................................................................................................................ 15

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5. COST.................................................................................................16

6. SCHEDULE.......................................................................................16

7. RISK ASSESSMENT ........................................................................18

8. CONFIRMED RESERVATIONS........................................................19

9. STUDY QUEUE.................................................................................25

10. ATTACHMENTS ...............................................................................26 A. Table of Acronyms.......................................................................................... 26 B. Scope Summary Diagram / Area Map ............................................................ 27


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 Southwestern Power Administration (SPA), to evaluate the West Star Energy Generation & Marketing request for 27MW of firm point to point transmission service. The time period for this transfer is from 6/1/2010 until 6/1/2040. The direction of the transaction is EES to SPA. This study was performed on the latest available 2010 – 2017 summer and 2011-2017 winter peak 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 overall scope of this project is summarized as follows:

A. Norfork-Calico Rock 161kV Transmission Line – Upgrade to 170 MVA The Norfork-Calico Rock 161kV transmission line overloads for the loss of the ANO-Fort Smith 500kV, ISES-KEO 500kV, or ISES-Dell 500kV transmission lines. It is required that the Norfork-Calico Rock 161kV transmission line be upgraded from a capacity of 148MVA to at least 170MVA.

B. Calico Rock-Melbourne 161kV Transmission Line – Upgrade to 170

MVA The Calico Rock-Melbourne 161kV transmission line overloads for the loss of the ANO-Fort Smith 500kV, ISES-KEO 500kV, or ISES-Dell 500kV transmission lines. It is required that the Calico Rock-Melbourne 161kV transmission line be upgraded from a capacity of 148MVA to at least 170MVA.

C. Melbourne-Sage 161kV Transmission Line – Upgrade to 180 MVA

The Melbourne-Sage 161kV transmission line overloads in the base case. It is required that the Melbourne-Sage 161kV transmission line be upgraded from a capacity of 148MVA to at least 180MVA.

D. Monette-Paragould 161kV Transmission Line – Upgrade to 170 MVA The Monette-Paragould 161kV transmission line overloads for the loss of the Plum Point-Shelby 500kV or Newport-Newport Industrial-Newport AB-Cash 161kV transmission lines. It is required that Monette-Paragould 161kV transmission line be upgraded from a capacity of 148MVA to at least 170MVA.

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E. Russellville South 161kV and Dardanelle Dam 161kV Substations Upgrade Russellville South – Dardanelle Dam Line Terminals

The Russellville South-Dardanelle Dam 161kV transmission line overloads for the loss of the ANO-Fort Smith 500kV transmission line. The Russellville South-Dardanelle Dam 161kV transmission line needs to have a capacity of 350MVA or greater on all components. The Dardanelle Dam switch #B2576 and Russellville South switch #B8160 are rated at 1200A or 335MVA. The switches need to be upgraded to 1600A. The rating of the Russellville South-Dardanelle Dam 161kV transmission line conductor must be verified that is currently rated above the required 350MVA.

F. Russellville South 161kV Substation

Upgrade Russellville South – Russellville East Line Terminal The Russellville South-Russellville East 161kV transmission line overloads for the loss of the ANO-Fort Smith 500kV transmission line. The Russellville South-Russellville East 161kV transmission line needs to have a capacity of 393MVA or greater on all components. The line conductor has a rated capacity of 396MVA, but the Russellville South 161kV switch #B8176 is rated at 1200A or 335MVA. The switch needs to be upgraded to 1600A. The upgrade of the Russellville South 161kV substation has been included in previous facility studies (OASIS request number 1460879, 1460881, and aggregate study ASA-2007-001, ASA-2007-002, ASA-2007-006, ASA-2007-007, & ASA-2007-008).

G. Russellville East-Russellville North 161kV Transmission Line –

Upgrade to 400 MVA The Russellville East-Russellville North 161kV transmission line overloads for the loss of the ANO-Fort Smith 500kV transmission line. It is required that the Russellville East-Russellville North 161kV transmission line be upgraded from a capacity of 396MVA to at least 400MVA. The upgrade of the Russellville East-Russellville North 161kV transmission line has been included in previous facility studies (OASIS aggregate studies ASA-2007-001, ASA-2007-002, ASA-2007-006, ASA-2007-007, & ASA-2007-008).

H. ANO-Russellville North 161kV Transmission Line - Upgrade to 449 MVA

The ANO-Russellville North 161kV transmission line overloads for the loss of the ANO-Fort Smith 500kV transmission line. It is required that ANO-Russellville North 161kV transmission line be upgraded from a capacity of 396MVA to at least 449MVA. The upgrade of the ANO-Russellville North 161kV transmission line is included in the 2008 ICT Base Plan. This project has a planned in-service date of 2012; therefore, the customer may be required to fund acceleration costs as this upgraded facility is needed in 2010.

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I. Danville-North Magazine REA 161kV Transmission Line – Upgrade to

176 MVA The Danville-North Magazine 161kV transmission line overloads for the loss of the ANO-Fort Smith 500kV transmission line. It is required that Danville-North Magazine 161kV transmission line be upgraded from a capacity of 148MVA to at least 176MVA. This line is owned by Southwest Electric Power Company. The owner will determine the cost to upgrade the line. The upgrade of the Danville-North Magazine 161kV transmission line is included in the 2008 ICT Base Plan.

1.3 Cost Summary • The estimated Total project cost is $50,041,000 Full Financial. This does not

include Tax Gross Up which may apply.

• The ICT has assigned $9,701,000 as Base Case upgrades and $40,340,000 as Supplemental Upgrade based on Attachment T of Entergy’s OATT.

1.4 Schedule Summary • Overall ISD for the entire project is 08/09/2012. ◦ The above ISD is based upon commencing the detailed definition phase work

in January of 2009, from that point moving forward into design work. ◦ T-line design schedule was developed assuming a grouping of resources for

similar sized projects. ◦ It was assumed that construction could only be done in off peak times. ◦ It was assumed that no special permits would be required.

2. 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. 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. Should the work contained within this Facility Study be approved, a detailed Safety Plan will be formulated and incorporated within the project plan.

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3. GENERAL ASSUMPTIONS • Upon receipt of formal approval from customer authorizing design and

construction, Entergy will prepare a detailed project execution plan and proceed with project execution.

• The ROW of the many line sections is known to range from mountainous to swampy. It’s known that some of the ROW(s) contain river crossings and highway crossings.

• All estimates for transmission line rebuilds were done assuming pole for pole replacements with direct embedded poles.

• No special construction equipment was included in the base cost of the project. • No alternative design approaches were pursued in this study. • All permits will be attainable in a reasonable period. • Due to timing and/or funding constraints, site visits, surveys, and soil borings

were not performed in order to develop this facility study. • All costs above represent good faith estimates in today’s dollars. Price

escalation has not been included. 4. SCOPE OF WORK

4.1 Norfork-Calico Rock 161kV Transmission Line – Upgrade to 170 MVA The following work is required:

Line Capacity MVA Existing Line Rating 148 Required Line Rating (Minimum) 170 Proposed Line Rating (based on Equipment to be installed) 246

• General: Line segment 901-05, Upgrade to at least 170MVA (610Amps)

o The line segment consists of wood pole H-frame and wood 3 pole angle and dead end structures with 336MCM ACSR conductor.

o The structures will be replaced with single steel poles in tangent locations and 3 steel pole, guyed structures for dead ends and angels. The new conductor will be 666MCM ACSR Flamingo wire and OPGW will be used as the shield wire.

• Right of Way: The ROW exists for this line segment and no new ROW will be required. However, Landowners will need to be notified prior to construction starting.

• Right of Way Clearing: Minimum clearing may be required. • Permitting and Wetland Mitigation: No special permitting or wetlands

mitigation is included in the scope of work. • Structures and Foundations:

o Install 81 steel poles (59 structures) o All structures are assumed to be direct embedded (running angles

and dead ends guyed)

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• Conductor: o Install 120klbs of 666MCM ACSR Flamingo conductor (17 circuit

miles) • Insulators:

o Install 249 insulator assemblies. • Shield Wire:

o Install 9miles of fiber optic shield wire (OPGW) • Removals:

o Remove 48 – H-frame structures o Remove 1 – 2 pole guyed, dead end structure. o Remove 10 – 3 pole, guyed, dead end structures. o Remove 8 miles of 3 phase 336MCM ACSR wire. o Remove 8 miles of 3/8” HSG shield wire.

• TASK Specific Assumptions: o Update Aspen Model with revised line impedances.

4.2 Calico Rock-Melbourne 161kV Transmission Line – Upgrade to 170 MVA

The following work is required: Line Capacity MVA Existing Line Rating 148 Required Line Rating (Minimum) 170 Proposed Line Rating (based on Equipment to be installed) 246

• General: Line Segment 901-04, Upgrade to at least 170MVA (610Amps)

o The line segment consists of 17 miles of wood pole H-frame and wood 3 pole angle and dead end structures with 336MCM ACSR conductor.

o The structures will be replaced with single steel poles in tangent locations, and 3 steel pole, guyed structures for dead ends and angels. The new conductor will be 666MCM Flamingo ACSR wire and OPGW will be used as the shield wire.




o Install 139 Steel Poles (113 Structures) o All Structures are assumed to be direct embedded (Running angles

and dead-ends guyed) • Conductor:

o Install 240klbs Lbs of 666MCM ACSR Flamingo conductor (17 circuit miles)

• Insulators: o Install 423 Insulator Assemblies

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• Shield Wire: o Install 18miles of fiber optic shield wire (OPGW)

• Removals: o Remove 100 – H-frame structures o Remove 2 – 2 pole guyed, dead end structures. o Remove 11 – 3 pole guyed, dead end structures. o Remove 17 miles of 3 phase 336MCM ACSR wire. o Remove 17 miles of 3/8” HSG shield wire.

• TASK Specific Assumptions: o Update Aspen Model with revised line impedances.

4.3 Melbourne-Sage 161kV Transmission Line – Upgrade to 180 MVA


• General: Line Segment 901-03, Upgrade to at least 180MVA (646Amps)

o The line segment consists of 5miles of wood pole H-frame and wood 3 pole angle and dead end structures with 336MCM ACSR conductor.

o The structures will be replaced with single steel poles in tangent locations and 3 steel pole, guyed structures for dead ends and angles. The new conductor will be 666MCM Flamingo ACSR wire and OPGW will be used as the shield wire.




o Install 40 steel poles (32 structures) o All structures are assumed to be direct embedded (Running angles

and Dead ends guyed) • Conductor:

o Install 70klbs of 666MCM ACSR Flamingo conductor (5 Circuit miles) • Insulators:

o Install 126 insulator assemblies • Shield Wire:


o Remove 28 – H-frame structures o Remove 3 – 3 pole, guyed, dead end structure. o Remove 1 – 3 pole guyed, angle structure.

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o Remove 5miles of 3 phase 336MCM ACSR wire. o Remove 5miles of 3/8” HSG shield wire.

• TASK Specific Assumptions: o Update Aspen Model with revised line impedances. o Revise relay settings at Sage substation for Norfork line panel.

4.4 Monette-Paragould 161kV Transmission Line – Upgrade to 170 MVA



o The line segment consists of 17 miles of wood pole H-frame, and wood 3 pole angle and dead end structures with 336MCM ACSR conductor.

o The structures will be replaced with single steel poles in tangent locations and 3 steel pole guyed structures for dead ends and angles. The new conductor will be 666MCM ACSR Flamingo wire and OPGW will be used as the shield.

o There are 5 new concrete pole structures already installed outside of the Paragould Substation (142-147). These structures will not be replaced. The existing 336 MCM ACSR will be replaced with 666MCM Flamingo ACSR. The existing 7#7 shield wire on these structures will be replaced with OPGW.




o Install 156 Steel Poles (142 structures) o All structures are assumed to be direct embedded (running angles

and dead ends guyed) • Conductor:

o Install 240klbs of 666MCM ACSR Flamingo conductor (17 circuit miles)

• Insulators: o Install 474 insulator assemblies

• Shield Wire: o Install 18miles of fiber optic shield wire (OPGW)

• Removals: o Remove 140 – H-frame structures. o Remove 1 – 3 pole guyed, angle dead end structure.

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o Remove 1 – 3 pole guyed, angle structure. o Remove 17 miles of 3 phase 336MCM ACSR wire. o Remove 17 miles of 3/8” HSG or 7#7 shield wire.

• TASK Specific Assumptions o Update Aspen model with revised line impedances. o Revise relay settings for Dell-Paragould line at Dell and Paragould.

4.5 Russellville South 161kV Substations - Upgrade Dardanelle Dam Line

Terminals • General: Upgrade Switch B8160 from 1200A to 2000A. • Site: No work required • Foundations: No work required. • Electrical: Remove existing 1200A motor operated switch B8160

(protecting the Dardanelle Dam line) and replace with a 2000A motor operated switch in the same position.

• Relay: No work required. • Relay Settings: Update Aspen model. Settings work required in

conjunction with line upgrade. • Communications and SCADA: No work required. • Metering: No work required. • TASK Specific Assumptions:

4.6 Paragould 161kV Substation – Upgrade Line Terminal Equipment • General: Upgrade Switch B6673 from 600A to 2000A. • Site: No work required. • Foundations: No work required. • Electrical: Remove existing 600A switch B6673 (protecting the Monett

Junction line) and replace with a 2000A switch in the same position. • Relay: No work required. • Relay Settings: Settings work required in conjunction with line upgrade. • Communications and SCADA: No work required. • Metering: No work required. • TASK Specific Assumptions:

4.7 Melbourne 161kV Substation – Upgrade Switch Jumpers • General: Upgrade jumpers on switches B0544 and B0426 • Site: No work required. • Foundations: No work required. • Electrical: Remove existing jumpers on switches B0544 and B0426 and

replace with a minimum of 666ACSR. • Relay: No work required.

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• Relay Settings: Settings work required in conjunction with line upgrade. • Communications and SCADA: No work required. • Metering: No work required. • TASK Specific Assumptions:

4.8 Dardanelle Dam 161kV Substation (SPA) – Upgrade Russellville South line Terminal • General: Upgrade Switch B2576 from 1200A to 2000A. • Site: No work required. • Foundations: No work required. • Electrical: Remove existing 1200A switch B2576 (protecting the

Russellville South line) and replace with a 2000A switch in the same position

• Relay: No work required. • Relay Settings: Update Aspen model, review and recalculate settings

for Russellville East panel based on new CTR. • Communications and SCADA: No work required. • Metering: No work required. • TASK Specific Assumptions:

4.9 Russellville South 161kV Substation - Upgrade Russellville East Line

Terminal • General: Upgrade Switch B8176 from 1200A to 2000A. • Site: No work required. • Foundations: No work required. • Electrical: Remove existing 1200A motor operated switch B8176

(protecting the Russellville East line) and replace with a 2000A motor operated switch in the same position.

• Relay: Design package and new cables for new switch and motor operator. • Relay Settings: Settings work required in conjunction with line upgrade. • Communications and SCADA: No work required. • Metering: No work required. • TASK Specific Assumptions:

4.10 Russellville East – Russellville North 161kV Transmission Line – Upgrade to 400MVA

Line Capacity MVA Existing Line Rating 396 Required Line Rating (Minimum) 400 Proposed Line Rating (based on Equipment to be installed) 545

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The following work is required:

• General: Line segment 898-02, Upgrade to at least 400MVA (1435Amps) o There is currently 1 lattice tower in use on this line segment. It is

located outside of the Russellville North Substation. This scope assumes that the lattice tower will remain in place and the new conductor will be attached with new insulators to this tower.

o The remaining H –frames and wood 3 pole structures will be replaced with single pole tangent structures and guyed steel 3 pole dead end and angle structures.




o Install 37 Steel poles (29 structures) o All structures are assumed to be direct embedded (Running angles


o Install 75klbs of 1272MCM ACSS Bittern conductor (3 circuit miles) • Insulators:

o Install 117 Insulator assemblies • Shield Wire:


o Remove 25 – H-frame structures o Remove 1 – 3 pole, guyed, angle structure o Remove 3 – 3 pole, guyed, dead end angle structures o Remove 3 miles of 3 phase 1534MCM ACAR o Remove 3 miles of 3/8” HSG shield wire

• TASK Specific Assumptions o Update Aspen model, review and revise settings for Russellville East

panel if necessary.

4.11 Arkansas Nuclear One 161kV Substation – Upgrade Russellville North Line Terminal

○ General: Motor Operated Switch B2512 (1600A) with 1600A line Trap is being upgraded to 3000A equipment under another project. No estimate is being provided.

○ Site: No work required. ○ Foundations: No work required. ○ Electrical: No work required. ○ Relay: No work required. ○ Relay Settings: No work required.

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○ Communications and SCADA: No work required. ○ Metering: No work required. ○ TASK Specific Assumptions:

4.12 Russellville North 161kV Substation – Upgrade ANO Line Terminal

○ General: Upgrade Motor Operated Switch B1292 and jumpers from 1600A to 2000A.

○ Site: No work required. ○ Foundations: No work required. ○ Electrical: Remove existing 1600A motor operated switch B1292

(protecting the Arkansas Nuclear One line) and replace with a 2000A motor operated switch in the same position.

○ Relay: Design package and new cables for new switch and motor operator.

○ Relay Settings: Settings work required in conjunction with line upgrade.

○ Communications and SCADA: No work required. ○ Metering: No work required. ○ TASK Specific Assumptions:

4.13 ANO-Russellville North 161kV Transmission Line - Upgrade to 449 MVA



o There are currently 12 Lattice towers in use on this line segment. There are 11 towers outside of the ANO substation and 1 tower outside of the Russellville North Substation. This scope assumes that the lattice towers will remain in place and the new conductor will be attached with new insulators to these towers. The remaining H-frames and wood 3 pole structures will be replaced with single pole tangent structures and guyed steel 3 pole dead end and angle structures.




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o Install 72 Steel poles (56 structures) o All structures are assumed to be direct embedded (Running angles


o Install 216klbs of 1272MCM ACSS Bittern conductor (9 circuit miles) • Insulators:

o Install 276 Insulator assemblies • Shield Wire:

o Install 9 meters of fiber optic shield wire (OPGW) • Removals:

o Remove 48 – H-frame structures o Remove 8 – 3 pole guyed structures o Remove 9 miles of 3 phase 1534MCM ACAR o Remove 9 miles of 3/8” HSG shield wire

• TASK Specific Assumptions o Settings: Update Aspen model, review and revise settings for

Russellville East panel if necessary.

4.14 Danville 161kV Substation – Upgrade N. Magazine Line Equipment ○ General: Upgrade strung conductors on the N. Magazine line

terminal. ○ Site: No work required. ○ Foundations: No work required. ○ Electrical: Upgrade the existing strung bus conductor on the N.

Magazine line to a minimum of 666ACSR conductor. ○ Relay: No work required. ○ Relay Settings: No work required. ○ Communications and SCADA: No work required. ○ Metering: No work required. ○ TASK Specific Assumptions:

4.15 Danville-North Magazine REA 161kV Transmission Line – Upgrade to 176 MVA

The upgrade of the Danville-North Magazine 161kV transmission line is included in the 2008 ICT Base Plan. The owner will determine the cost to upgrade the line.

The Right of Way for this segment is owned by Arklahoma Corporation. The line is maintained by SWEPCO as defined by the Corporation agreement. The cost to upgrade this line will be determined by APEW and approved by the Arklahoma Corporation.

As a result of this line rebuild, new line relay settings will be required for the existing line relays for substations at the Danville 161kV substation and will be completed by Entergy and coordinated with SWEPCO.

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5. COST

The ICT has reviewed and determined the required upgrades to be considered Base Plan and Supplemental Upgrades. 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. Entergy incurs a tax liability proportional to the amount of customer contributions. In addition to proposed project costs, the customer may be charged a “Tax gross-up” at applicable rates. Rates are subject to change. Current rate for EAI is 32.693% and is not included in any of the estimates.

Projected Costs

TOTAL Base Case Supplemental Norfork to Calico Rock T-line $7,656,000 $7,656,000 Calico Rock to Melbourne T-line $13,274,000 $13,274,000 Melbourne to Sage T-line $4,207,000 $4,207,000 Monette to Paragould T-line $10,781,000 $10,781,000

Paragould 161kV Sub $87,000 $87,000 Melbourne 161kV Sub $60,000 $60,000 Dardanelle Dam 161kV Sub (SPA) $69,000 $69,000 Russellville South 161kV Sub $180,000 $180,000 ANO to Russellville North T-line $9,511,000 $9,511,000 Russellville East to Russellville North T-line $4,026,000 $4,026,000

Danville – North Magazine REA T-line By Others Danville 161kV Substation $107,000 $107,000

Russellville North Substation $83,000 $83,000

TOTAL OF ABOVE $50,041,000 $9,701,000 $40,340,000 NOTE:

1. Tax gross-up is not included in the above estimates. 6. SCHEDULE

A detailed schedule will be prepared subsequent to customer approval to proceed with the project. Based on the Work Order duration schedules listed below, the overall project in-service date is projected to be 08/10/2011. The following are rough durations:

TASK Name / Number Proposed Start Date Proposed ISD Detailed Definition Phase 1/05/2009 11/02/2009

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(All Work Orders) Norfork to Calico Rock T-Line Rebuild

7/5/2011 11/13/2012

Calico Rock to Melbourne T-Line Rebuild

11/2/2009 6/30/2011

Melbourne to Sage T-Line Rebuild

7/5/2011 7/2/2012

Monette to Paragould T-Line Rebuild

11/2/2010 8/9/2012

Russellville East to Russellville North T-Line Rebuild

11/2/2009 12/15/2010

ANO to Russellville North T-Line Rebuild

11/2/2010 3/13/2012

Paragould Substation 4/11/2011 10/31/2011 Melbourne Substation 11/2/2010 11/22/2010 Dardanelle Substation 11/2/2009 5/19/2010 Russellville North Substation

11/2/2009 6/9/2010

Danville Substation 11/2/2009 6/9/2010 Russellville South Substation

11/2/2009 6/9/2010

Danville to North Magazine REA T-Line Rebuild

By Others By Others

Notes to Duration Schedules: • All construction work requiring outages will be performed during 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, last minute denial of outages by the SOC/TOC along with resulting schedule delay is possible.

• Substation construction will be completed during transmission line outages. • Construction resources are available when required. • Transmission Line and Substation projects will begin subsequent to Definition

phase Project Execution Plan. • Schedule was developed assuming that smaller line sections could be grouped

for design and larger sections grouped together for design. • This schedule does not account for adverse weather conditions.

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• Schedule durations are high level estimates at this time. A detailed schedule will be prepared upon project approval.

7. RISK ASSESSMENT

• List project risks • List contingency included in the project cost / schedule

Risk Comment Impact

Material costs steel & Equipment Rising steel, copper, fuel and other market conditions could greatly affect estimated cost. ****

Lay-down areas Cost to be determined during detailed scoping. *

Weather & Equipment Lead Times

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

T-Line Structures Count can change Estimates based on pole for pole replacement of structures. ***

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. **

Terrain challenges, specifically rock drilling

Rock drilling is expected, but costs depend upon type of rock and accessibility for drilling equipment. ****

Higher costs of contractor labor

It is likely that current market conditions will begin affecting the contract labor and equipment costs. ****

Availability of resources

If resources are unavailable, contract resources will be needed to perform Design and / or Construction oversight. *

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


8. CONFIRMED RESERVATIONS OASIS# PSE MW Begin End 140912 NRG Power Marketing 103 01/01/98 01/01/08 250778 (delisting) Entergy Services, Inc. (EMO) 1 07/02/98 07/01/11 392740 Ameren Energy Inc. 165 04/12/99 01/01/09 569011 Entergy Services, Inc. (EMO) 242 03/01/00 01/01/14 731017 South Mississippi Electric Power

Assoc. 75 01/01/01 06/01/09

759196 Entergy Services (EMO) 143 01/01/01 01/01/21 759294 East Texas Electric Cooperative 31 01/01/01 01/01/18 810207 South Mississippi Electric Power

Assoc. 300 01/01/02 01/01/20

810234 South Mississippi Electric Power Assoc.

300 01/01/02 01/01/20

850239 Municipal Energy Agency of Mississippi

19 05/01/01 01/01/10


13 05/01/01 06/01/10


13 05/01/01 06/01/10


51 01/01/02 01/01/18

1024194 City Water & Light, Jonesboro 83 01/01/03 01/01/10 1024198 City Water & Light, Jonesboro 168 01/01/03 01/01/10 1035455 South Mississippi Electric Power

Assoc. 280 01/01/03 01/01/08


280 01/01/08 01/01/21

1084342 East Texas Electric Cooperative 50 01/01/05 01/01/09 1084344 East Texas Electric Cooperative 50 01/01/05 01/01/09 1084345 East Texas Electric Cooperative 75 01/01/05 01/01/09 1096986 Tennessee Valley Auth BPT 73 09/01/03 09/01/13 1099991 City Water & Light, Jonesboro 83 01/01/10 01/01/16 1099997 City Water & Light, Jonesboro 168 01/01/10 01/01/16 1105665 Entergy Services, Inc. (EMO) 185 02/01/03 02/01/16 1105666 Entergy Services, Inc. (EMO) 91 02/01/03 02/01/27

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OASIS# PSE MW Begin End 1105668 Entergy Services, Inc. (EMO) 206 02/01/03 02/01/27 1126821 Entergy Services, Inc. (EMO) 101 05/01/04 05/01/29 1139973 South Mississippi Electric Power

Assoc. 95 05/01/03 12/30/28


95 05/01/04 12/31/29


95 05/01/05 12/31/29


130 01/01/03 01/01/20

1151106 Entergy Services, Inc. (EMO) 20 06/01/10 06/01/29 1161925 Cleco Power LLC (Gen) 12 08/01/03 01/01/10 1161927 Cleco Power LLC (Gen) 7 08/01/03 01/01/10 1161928 Cleco Power LLC (Gen) 7 08/01/03 01/01/10 1168061 Entergy Services, Inc. (EMO) 80 08/01/04 02/01/28 1168408 Entergy Services, Inc. (EMO) 247 08/01/04 02/01/28 1192287 (1140407) Entergy Services, Inc. (EMO) 725 01/01/05 09/01/33 1202470 NRG Power Marketing 91 04/01/04 04/01/09 1210356 Entergy Services, Inc. (EMO) 290 07/01/05 07/01/07 1210357 Entergy Services, Inc. (EMO) 100 07/01/05 07/01/07 1272606 (renewal) Entergy Services, Inc. (EMO) 150 05/01/05 05/01/07 1286481 Merrill Lynch Commodities 11 01/01/00 01/01/10 1289686 (delisting) Entergy Services Inc. (EMO) 1 06/01/07 06/01/30 1294132 Entergy Services, Inc. (EMO) 526 01/01/06 01/01/35 1309874 East Texas Electric Cooperative 75 01/01/09 01/01/17 1309875 East Texas Electric Cooperative 50 01/01/09 01/01/17 1309876 East Texas Electric Cooperative 50 01/01/09 01/01/17 1310448 (1284799)

(delisting) Entergy Services Inc. (EMO) 1 06/01/07 06/01/30

1321868 (renewal) NRG Power Marketing 320 01/01/06 01/01/07 1328125 CLECO Power Marketing 35 01/01/06 01/01/11 1340017 Plum Point Energy Associates 40 03/01/10 03/01/40 1340019 Plum Point Energy Associates 35 03/01/10 03/01/40 1340028 Plum Point Energy Associates 50 03/01/10 03/01/30 1340029 Plum Point Energy Associates 50 03/01/10 03/01/30

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OASIS# PSE MW Begin End 1340665 Entergy Services, Inc. (EMO) 200 01/01/06 01/01/09 1340673 Entergy Services, Inc. (EMO) 50 06/01/07 06/01/08 1340674 Entergy Services, Inc. (EMO) 50 06/01/08 06/01/09 1346435 Entergy Services, Inc. (EMO) 100 06/01/07 06/01/08 1346437 Entergy Services, Inc. (EMO) 100 06/01/08 06/01/09 1346440 Entergy Services, Inc. (EMO) 200 06/01/07 06/01/08 1346441 Entergy Services, Inc. (EMO) 200 06/01/08 06/01/09 1346444 Entergy Services, Inc. (EMO) 179 02/01/07 02/01/08 1348508 CLECO Power Marketing 10 01/01/06 01/01/10 1352704 (1340032) Plum Point Energy Associates 5 03/01/10 03/01/40 1353140 Constellation Energy Group 10 01/01/06 01/01/07 1353141 Constellation Energy Group 5 01/01/06 01/01/07 1353344 (renewal) Merrill Lynch Commodities 85 10/01/05 10/01/06 1353393 (renewal) Merrill Lynch Commodities 4 11/01/05 11/01/06 1356328 Municipal Energy Agency of

Mississippi 40 06/01/10 06/01/40

1366979 MidAmerican Energy 50 01/01/06 01/01/07 1366980 MidAmerican Energy 50 01/01/06 01/01/07 1366981 MidAmerican Energy 50 01/01/06 01/01/07 1366982 MidAmerican Energy 50 01/01/06 01/01/07 1371416 NRG Power Marketing 100 03/01/06 03/01/07 1371481 (delisting) Entergy Services, Inc. (EMO) 1 01/01/06 01/01/07 1372645 Morgan Stanley Commodities Group 102 01/01/07 01/01/08 1372646 Morgan Stanley Commodities Group 102 01/01/07 01/01/08 1373112 Louisiana Energy & Power Authority 61 01/01/06 01/01/07 1373643 City of Conway 25 03/01/10 03/01/40 1373714 East Texas Electric Cooperative 63 01/01/10 01/01/30 1375001 NRG Power Marketing 3 07/01/06 07/01/07 1375299 Louisiana Generating LLC 11 03/01/06 03/01/11 1375300 Louisiana Generating LLC 8 03/01/06 03/01/11 1375301 Louisiana Generating LLC 5 03/01/06 03/01/11 1375559 CLECO Power LLC 675 12/01/06 12/01/16 1376208 Louisiana Energy & Power Authority 6 02/01/06 02/01/07 1380484 Osceola Light & Power 9 09/01/09 09/01/39 1381068 Plum Point Energy Associates 100 06/01/10 06/01/11

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OASIS# PSE MW Begin End 1381247 Constellation Energy Group 140 01/01/06 01/01/07 1381248 (1349801) City of West Memphis 70 01/01/06 01/01/07 1381312 Constellation Energy Group 240 01/01/06 07/01/07 1381317 Constellation Energy Group 70 01/01/06 01/01/07 1381318 Constellation Energy Commodities

Group 70 01/01/06 01/01/07

1381322 Constellation Energy Commodities Group

6 01/01/06 06/01/07

1381398 Constellation Energy Group 34 01/01/06 01/01/36 1381400 Constellation Energy Group 34 01/01/06 01/01/36 1381404 Constellation Energy Group 17 01/01/06 01/01/36 1381406 (1325187) Constellation Energy Group 17 01/01/06 01/01/36 1382543 Mid American Energy Company 100 03/01/06 03/01/07 1382544 Mid American Energy Company 100 03/01/06 03/01/07 1383852 AECC 550 01/01/07 01/01/17 1385131 Ameren 12 06/01/06 06/01/07 1385835 (1363730) City of Prescott 22 04/01/06 04/01/09 1385842 South Mississippi Electric Power

Assoc. 100 38

01/01/09 01/01/10

01/01/10 01/01/11

1387272 CLECO Power 11 04/01/06 04/01/16 1387274 CLECO Power 16 04/01/06 04/01/07 1387275 CLECO Power 16 04/01/07 04/01/08 1389008 NRG Power Marketing 270 06/01/07 06/01/08 1389848 Louisiana Energy & Power Authority 6 02/01/07 02/01/08 1389848 Louisiana Energy & Power Authority 6 02/01/07 02/01/08 1393874 NRG Power Marketing 5 09/01/06 09/01/07 1394479 Louisiana Generating LLC 2 06/01/06 06/01/07 1396788 Constellation Energy Commodities 70 06/01/06 06/01/07 1401985 Constellation Commodities Group 42 08/01/06 08/01/36 1403756 Constellation Commodities Group 100 01/01/07 01/01/08 1403757 Constellation Commodities Group 100 01/01/07 01/01/08 1406786 South Mississippi Electric Power

Assoc. 100 04/01/10 04/01/40

1407894 Morgan Stanley Commodities Group 102 01/01/08 01/01/09 1407895 Morgan Stanley Commodities Group 102 01/01/08 01/01/09

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OASIS# PSE MW Begin End 1408199 South Mississippi Electric Power

Assoc. 100 04/01/10 04/01/40

1408981 NRG 92 01/01/07 01/01/10 1410022 (1340037) City of North Little Rock 60 03/01/10 03/01/40 1412068 NRG 103 01/01/07 01/01/08 1413110 NRG Power Marketing 100 01/01/07 01/01/09 1414925 Constellation Commodities Group 22 01/01/07 01/01/08 1414927 Constellation Commodities Group 50 01/01/07 01/01/08 1416650 NRG Power Marketing 100 01/01/07 01/01/08 1422496 Constellation Commodities Group 57 01/01/07 01/01/08 1422498 Constellation Commodities Group 9 01/01/07 01/01/08 1422708 Entergy Services, Inc. (EMO) 1 01/01/07 01/01/27 1424384 Constellation Commodities Group 100 01/01/07 01/01/08 1425495 East Texas Electric Cooperative 50 03/01/10 03/01/45 1426761 Merrill Lynch Commodities, Inc. 85 11/01/06 11/01/07 1426762 Merrill Lynch Commodities, Inc. 4 11/01/06 11/01/07 1431165 Cargill Alliant 103 01/01/08 01/01/09 1431621 South Mississippi Electric Power

Assn. 200 01/01/07 01/01/08

1432487 Arkansas Electric Cooperative Corp. 50 12/01/07 12/01/19 1443976 (1424383) Constellation Commodities Group 9 01/01/07 01/01/08 1435972 Entergy Services, Inc. (EMO) 150 05/01/07 05/01/10 1435973 Entergy Services, Inc. (EMO) 135 05/01/08 05/01/10 1436590 MidAmerican Energy 50 01/01/07 01/01/08 1436591 MidAmerican Energy 50 01/01/07 01/01/08 1436592 MidAmerican Energy 50 01/01/07 01/01/08 1436593 MidAmerican Energy 50 01/01/07 01/01/08 1440358 NRG Power Marketing 100 03/01/07 03/01/08 1442295 NRG Power Marketing 3 07/01/07 07/01/09 1442453 NRG Power Marketing 320 06/01/07 06/01/26 1448054 NRG Power Marketing 103 01/01/08 01/01/09 1448057 NRG Power Marketing 103 01/01/08 01/01/09 1449494 Entergy Services, Inc. (EMO) 154 06/01/07 06/01/09 1449495 Entergy Services, Inc. (EMO) 322 06/01/09 06/01/59 1449881 Cargill Power 103 01/01/08 01/01/09

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OASIS# PSE MW Begin End 1452307 NRG Power Marketing 100 01/01/08 01/01/09 1452308 NRG Power Marketing 100 01/01/08 01/01/09 1452603 NRG Power Marketing 100 09/01/07 09/01/08 1453402 NRG Power Marketing 103 01/01/09 01/01/10 1456636 CLECO Power LLC 10 10/01/07 10/01/12 1458787 Louisiana Energy & Power Authority 2 03/31/07 03/31/08 1460898 Louisiana Energy & Power Authority 3 01/01/09 01/01/30 1460899 Louisiana Energy & Power Authority 5 01/01/09 01/01/30 1461442 Louisiana Energy & Power Authority 12 01/01/09 01/01/30 1464028 East Texas Electric Coop 168 01/01/10 01/01/40 1466197 NRG Power Marketing 206 01/01/09 01/01/10 1466561 Constellation Energy 50 01/01/08 01/01/09 1466562 Constellation Energy 25 01/01/08 01/01/09 1470811 East Texas Electric Coop 186 01/01/10 01/01/40 1477069 Entergy Services 10 11/01/07 11/01/37 1477256 NRG Power Marketing 103 01/01/08 01/01/09 1479051 Ameren Energy Mktg 103 07/01/08 07/01/09 1483485 Entergy Services (EMO) 100 01/01/08 01/01/11 1483490 Entergy Services (EMO) 1 01/01/08 01/01/11 1485805 NRG Power Marketing 103 07/01/08 07/01/09 1487880 NRG Power Marketing 300 01/01/08 01/01/10 1494443 Constellation Energy 35 01/01/08 01/01/09 1494445 Constellation Energy 75 01/01/08 01/01/09 1494446 Constellation Energy 75 01/01/08 01/01/09 1494450 Constellation Energy 25 01/01/08 01/01/09 Pre-888 Transactions http://oasis.e-terrasolutions.com/documents/EES/Pre-Order888Transactions.xls

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http://oasis.e-terrasolutions.com/documents/EES/Pre-Order888Transactions.xls


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9. STUDY QUEUE OASIS # PSE MW Begin End 1460876 Aquila Networks - MPS 75 3/1/2009 3/1/2029 1460878 Aquila Networks - MPS 75 3/1/2009 3/1/2029 1460879 Aquila Networks - MPS 75 3/1/2009 3/1/2029 1460881 Aquila Networks – MPS 75 3/1/2009 3/1/2029 1460900 Louisiana Energy & Power Authority 116 1/1/2009 1/1/2030 1468285 MidAmerican Energy, Inc. 103 9/1/2007 9/1/2008 1468286 MidAmerican Energy, Inc. 103 9/1/2007 9/1/2008 1468288 MidAmerican Energy, Inc. 103 1/1/2008 1/1/2009 1468289 MidAmerican Energy, Inc. 103 1/1/2008 1/1/2009 1478781 Entergy Services, Inc. (EMO) 804 1/1/2008 1/1/2058 1481059 Constellation Energy Group 60 2/1/2011 2/1/2030 1481111 City of Conway 50 2/1/2011 2/1/2046 1481119 Constellation Energy Group 30 2/1/2011 2/1/2030 1481235 Louisiana Energy & Power Authority 50 2/1/2011 2/1/2016 1481438 NRG Power Marketing 20 2/1/2011 2/1/2021 1483241 NRG Power Marketing 103 1/1/2010 1/1/2020 1483243 NRG Power Marketing 206 1/1/2010 1/1/2020 1483244 NRG Power Marketing 309 1/1/2010 1/1/2020 1520043 Municipal Energy Agency of Miss 20 1/1/2011 1/1/2026 1543292 Constellation Energy Group 215 4/1/2009 4/1/2010 1543616 CLECO Power Marketing 17 1/1/2009 1/1/2011 1543621 CLECO Power Marketing 162 1/1/2010 1/1/2019 1546108 (delisting) Entergy Services, Inc. (EMO) 1 1/1/2011 1/1/2051


10. ATTACHMENTS A. Table of Acronyms

ACSR Aluminum Conductor Steel Reinforced ACSS Aluminum Conductor Steel Supported ADEQ Arkansas Department of Environmental Quality AFUDC Allowance for Funds Used During Construction ATC Available Transfer Capability EES Entergy Control Area EHV Extra-High Voltage ICT Independent Coordinator of Transmission kV Kilo-Volt MCM (M) Thousand Circular Mils MVA Mega-Volt Amp MW Mega-Watt NPDES National Pollution Discharge Elimination System NOI Notice of Intent OASIS Online Access and Same-time Information System OATT Open Access Transmission Tariff OG&E Oklahoma Gas & Electric POD Point of Delivery POR Point of Receipt SES Steam Electric Station SOC System Operations Center SHPO Arkansas State Historic Preservation Office SHV Super High Voltage SW Switch Station SWEPCO Southwest Electric Power Company TOC Transmission Operations Center WMUC City of West Memphis Control Area

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B. Scope Summary Diagram / Area Map

Location Description Drawing Number

Norfork to Calico Rock Area Map B – 1 Calico Rock to Melbourne Area Map B – 2 Melbourne to Sage Area Map B – 3 Monette Jct to Paragould Area Map B – 4 Russellville East to Russellville North Area Map B – 5 Arkansas Nuclear One to Russellville North Area Map B – 6 Danville to North Magazine Area Map B - 7

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C. One Line Drawings Substation Drawing Number Calico Rock 161 kV Substation A3207SO1 Melbourne 161 kV Substation A3243SO1 Sage 161 kV Switch Station A2245SO1 Paragould 161/115 kV Substation A3282SO1 Monette Junction161/33 kV Substation A3281SO1 Russellville South 161 kV Substation A3263SO1 Dardanelle 161 kV Substation A3216SO1 Russellville East 161 kV Substation A3261SO1 Russellville North 161 kV Substation A3262SO1 ANO 500/161 kV Substation A2001SO1 Danville 161 kV Substation A3215SO1

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D. Duration Schedule ○ Summary level Schedule (Schedule_Summary_Facility Study 1547988_07112008)

Included in attachments.

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1. PROJECT SUMMARY1.1 Background and Project Need1.2 Scope SummaryA. Norfork-Calico Rock 161kV Transmission Line – Upgrade to 170 MVAB. Calico Rock-Melbourne 161kV Transmission Line – Upgrade to 170 MVAC. Melbourne-Sage 161kV Transmission Line – Upgrade to 180 MVAD. Monette-Paragould 161kV Transmission Line – Upgrade to 170 MVAE. Russellville South 161kV and Dardanelle Dam 161kV SubstationsF. Russellville South 161kV SubstationG. Russellville East-Russellville North 161kV Transmission Line – Upgrade to 400 MVAH. ANO-Russellville North 161kV Transmission Line - Upgrade to 449 MVAI. Danville-North Magazine REA 161kV Transmission Line – Upgrade to 176 MVA

1.3 Cost Summary1.4 Schedule Summary

2. SAFETY AWARENESS3. GENERAL ASSUMPTIONS4. SCOPE OF WORK 4.1 Norfork-Calico Rock 161kV Transmission Line – Upgrade to 170 MVA4.2 Calico Rock-Melbourne 161kV Transmission Line – Upgrade to 170 MVA4.3 Melbourne-Sage 161kV Transmission Line – Upgrade to 180 MVA4.4 Monette-Paragould 161kV Transmission Line – Upgrade to 170 MVA4.5 Russellville South 161kV Substations - Upgrade Dardanelle Dam Line Terminals4.6 Paragould 161kV Substation – Upgrade Line Terminal Equipment4.7 Melbourne 161kV Substation – Upgrade Switch Jumpers 4.8 Dardanelle Dam 161kV Substation (SPA) – Upgrade Russellville South line Terminal4.9 Russellville South 161kV Substation - Upgrade Russellville East Line Terminal4.10 Russellville East – Russellville North 161kV Transmission Line – Upgrade to 400MVA4.11 Arkansas Nuclear One 161kV Substation – Upgrade Russellville North Line Terminal4.12 Russellville North 161kV Substation – Upgrade ANO Line Terminal4.13 ANO-Russellville North 161kV Transmission Line - Upgrade to 449 MVA4.14 Danville 161kV Substation – Upgrade N. Magazine Line Equipment4.15 Danville-North Magazine REA 161kV Transmission Line – Upgrade to 176 MVA

5. COST6. SCHEDULE7. RISK ASSESSMENT8. CONFIRMED RESERVATIONS9. STUDY QUEUE10. ATTACHMENTSA. Table of Acronyms B. Scope Summary Diagram / Area Map

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