ictt-2010-150 transmission service facilities study …the equipment at toledo bend needs to be...

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TRANSMISSION LINE & SUBSTATION PROJECTS

COMPANY:ENTERGY SERVICES, INC.

CUSTOMER: ENTERGY SERVICE INC, (SPO)

FACILITIES STUDY

EJO NO. F4PPMS0250

ICTT-2010-150

TRANSMISSION SERVICE FACILITIES STUDY OASIS 74900000

Revision: 0

Rev Issue Date

Description of Revision Prepared

By Approved

By

A 04/20/11 Shell for team input Ibrahim Khan

Charles Newell

B 04/27/11 Added contents of solution set Ibrahim Khan

Charles Newell

C 05/16/11 Submitted for JET Vote Ibrahim Khan

Charles Newell

D 05/21/11 Submitted to PD Ibrahim Khan

Charles Newell

E 05/24/11 Document Re-format GWR

0 6/14/11 ICT Determines Upgrade Classification Sherri Maxey

Benjamin Roubique

OASIS 74900000 Entergy Services, Inc. (SPO) Facilities Study

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TABLE OF CONTENTS

1. PROJECT SUMMARY ....................................................................... 4

1.1 Background and Project Need ................................................................................. 4 1.2 Scope Summary ....................................................................................................... 4

1.2.1 2011-2013 Approved Entergy Construction Plan Projects Needed by 6/1/2012 ................................................................................................................ 4

1.2.2 2011-2013 Approved Entergy Construction Plan Projects Needed by 6/1/2014 ................................................................................................................ 4

1.2.3 Upgrade the Toledo Bend-Leach 138kV transmission line. ....................... 5

1.2.4 Upgrade the Newton Bulk-Leach 138kV transmission line. ....................... 5

1.2.5 Install a 3rd 525MVA, 345/138kV autotransformer at Grimes. .................. 5

1.2.6 Upgrade Grimes-Mt. Zion 138kV transmission line. .................................. 6

1.2.7 Construct a new 230kV substation, add a 2nd 500/230kV Hartburg autotransformer, and build a new 230kV line from Hartburg 230kV to the new 230kV substation. .................................................................................................. 6

1.3 Required Redispatch: ............................................................................................ 7 1.4 CLECO Affected System Study ............................................................................. 8 1.5 Cost Summary ....................................................................................................... 8 1.6 Schedule Summary ............................................................................................... 8

2. SAFETY REQUIREMENTS ................................................................ 8

3. GENERAL ASSUMPTIONS: .............................................................. 8

4. SCOPE OF WORK ............................................................................. 9

4.1 Upgrade the Toledo Bend-Leach 138kV transmission line. ...................................... 9 4.2 Toledo Bend 138kV Replace line bay bus: ............................................................. 11 4.3 Upgrade Newton Bulk-Leach 138kV transmission line. .......................................... 12 4.4 Grimes Substation .................................................................................................. 14 4.5 Mt Zion to Grimes 138 kV new line ......................................................................... 24

4.6 New Substation (NSS) – 230 kV: ........................................................................... 27 4.7 Hartburg Substation – 500/230 kV: ........................................................................ 33 4.8 New 230 kV line to New Substation from Hartburg ................................................ 43 4.9 Line Cut-in into New SS (Helbig to McLewis line) .................................................. 46 4.10 Line Cut-in New SS (Sabine to Georgetown lines) ............................................... 47

4.11 Sabine Substation – 230 kV: ................................................................................ 48

4.12 Helbig Substation – 230 kV: ................................................................................. 51

4.13 Georgetown Substation – 230 kV: ........................................................................ 52

5. COST ............................................................................................... 53

Estimated Task Costs .................................................................................................. 53

6. UPGRADE CLASSIFICATION ......................................................... 54


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7. SCHEDULE ...................................................................................... 54

8. RISK ASSESSMENT ....................................................................... 57

9. CONFIRMED RESERVATIONS ....................................................... 58

10. PRE-888 TRANSACTIONS .............................................................. 62

11. STUDY QUEUE ................................................................................ 63

12. ATTACHMENTS .............................................................................. 64

A Table of Acronyms ........................................................................................... 64

B Scope Summary Diagram / Area Maps ........................................................... 66

C One line & Substation Layout Drawing ............................................................ 66

D – Duration Schedules ...................................................................................... 66


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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 transfer capability across Entergy’s transmission system from Entergy (EES) to Entergy (EES) to evaluate the Entergy Services request for 620MW of yearly network transmission service. The time period for this transfer is from 6/1/2012 until 6/1/2042. The direction of the transaction is EES to EES. The study was performed on the latest available 2012-2020 winter, 2013-2020 summer peak seasonal models, and the June 2012 – October 2012 monthly cases using PSS/E and MUST software by Power Technologies Incorporated (PTI). The facilities study identifies any transmission constraints resulting from the requested power transfer. The facilities study also includes cost estimates to correct any transmission constraints.

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 Needed by 6/1/2012

The following projects are approved in the 2011-2013 Entergy Construction Plan. These projects are required to be in-service prior to the start of transmission service.

Big Three-Carlyss 230kV: Upgrade bus, switch, and jumpers at Carlyss 230kV substation – 2011 Expected ISD

Bayou LaBoutte: Construct new 500-230 kV Substation – 2011 Expected ISD

Addis-Cajun 230kV Line Upgrade to 637MVA o Upgrade of Entergy owned equipment was completed in early 2011. o Upgrade of Louisiana Generating LLC owned equipment at Big Cajun #1

230kV substation – Winter 2011 Expected ISD

1.2.2 2011-2013 Approved Entergy Construction Plan Projects Needed by 6/1/2014

The following projects are approved in the 2011-2013 Entergy Construction Plan. These projects are required to be in-service prior to the 6/1/2014.

Toledo Bend-Van Ply 138kV line: Upgrade CT at Toledo Bend– 2011 Expected ISD


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1.2.3 Upgrade the Toledo Bend-Leach 138kV transmission line.

The Toledo Bend-Leach 138kV transmission line overloads for the loss of the Cypress-Hartburg 500kV, Grimes-Crockett 345kV, Hartburg -Mt. Olive 500kV, or Cooper-Leesville 138kV transmission line. The Toledo Bend-Leach 138kV transmission line needs to have a capacity of 179MVA or greater on all components. The equipment at Toledo Bend needs to be upgraded to increase the rating of the transmission line from 134MVA to 143MVA. The upgrade of the Toledo Bend equipment (which increases the line rating to 143MVA) is proposed in the 2011-2013 Entergy Construction Plan with a 2013 Expected ISD. It is required that the Toledo Bend-Leach 138kV transmission line be upgraded from a capacity of 143MVA to at least 179MVA. The proposed upgrade is 211MVA. The amount of capacity created by this upgrade is 68 MW, and the customer’s use of the capacity created is 25 MW.

1.2.4 Upgrade the Newton Bulk-Leach 138kV transmission line.

The Newton Bulk-Leach 138kV transmission line overloads for the loss of the Cypress-Hartburg 500kV, Hartburg-Mt. Olive 500kV, or Cooper-Leesville 138kV transmission line. The Newton Bulk-Leach 138kV transmission line needs to have a capacity of 167MVA or greater on all components. The equipment at Newton Bulk needs to be upgraded to increase the rating of the transmission line from 141MVA to 143MVA. The upgrade of the Newton Bulk equipment (which increases the line rating to 143MVA) is proposed in the 2011-2013 Entergy Construction Plan with a 2013 Expected ISD. It is required that the Newton Bulk-Leach 138kV transmission line be upgraded from a capacity of 143MVA to at least 177MVA. The proposed upgrade is 211MVA. The amount of capacity created by this upgrade is 68 MW, and the customer’s use of the capacity created is 21 MW.

1.2.5 Install a 3rd 525MVA, 345/138kV autotransformer at Grimes.

The Grimes 345/138kV autotransformer #1 or #2 overloads for the loss of the Grimes 345/138kV autotransformer #2 or #1. It is required that a 3rd 525MVA, 345/138kV autotransformer at Grimes be installed.

The amount of capacity created by this upgrade is 525 MW, and the customer’s use of the capacity created is 23 MW.


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The 3rd 345/138kV Grimes autotransformer has been identified as a required upgrade in prior Facilities Studies (OASIS request #74846159 and #74899996). If both the prior transmission service requests (OASIS #74846159 and #74899996) and proposed upgrade is withdrawn, this customer would be responsible for this upgrade.

1.2.6 Upgrade Grimes-Mt. Zion 138kV transmission line.

The Grimes-Mt. Zion 138kV transmission line overloads for the loss of the Grimes-Bentwater-Walden-April-Conroe 138kV or the Cypress-Hartburg 500kV transmission line. It is required that the Grimes-Mt. Zion 138kV transmission line be upgraded from a capacity of 206MVA to at least 250MVA. The proposed upgrade is 260MVA. The amount of capacity created by this upgrade is 54 MW, and the customer’s use of the capacity created is 31 MW. The Grimes-Mt. Zion line upgrade has been identified as a required upgrade in a prior Facilities Study (OASIS request #74846159). If the prior transmission service request (OASIS #74846159) and proposed upgrade is withdrawn, this customer would be responsible for this upgrade.

1.2.7 Construct a new 230kV substation, add a 2nd 500/230kV Hartburg autotransformer, and build a new 230kV line from Hartburg 230kV to the new 230kV substation.

The following constraints are observed for this transmission service request:

Limiting Element Contingency Element

Hartburg-Inland Orange-McLewis-Helbig 230kV

Cypress-Hartburg 500kV

Mossville-Nelson 138kV

Marshall-Mossville 138kV

Carlyss-Rose Bluff-PPG-Verdine 230kV

Carlyss-Nelson 230kV

Amelia-Helbig 230kV

Sabine-Big Three 230kV

Hollywood-Nelson 138kV

Nelson 500/230kV autotransformer

Hartburg 500/230kV autotransformer

Kountze-Lumberton 138kV Cypress-Bevil-Amelia 230kV

Cypress-Bevil-Amelia 230kV Hartburg 500/230kV autotransformer

Cypress 500/138kV autotransformer





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It is required that the following project be constructed:

New substation: Build a new 230kV five terminal substation.

Re-route the McLewis-Helbig 230kV transmission line (L-195) into the new five breaker ring bus switchyard; connecting the McLewis and Helbig 230kV substations to the new switchyard.

Re-route the Sabine-Georgetown 230kV transmission line (L-572) into the new five breaker ring bus switchyard; connecting the Sabine and Georgetown 230kV substations to the new switchyard.

Hartburg – Install a 2nd 800MVA, 500/230kV autotransformer.


Build a new 230kV line from Hartburg 230kV to the New Substation.


Replace 8 breakers at Sabine 230kV (13180, 13185, 13190, 13195, 13200, 13255, 13260, and 13265) with an interrupting rating of at least 47kA. Upgrade to 63kA IPO breakers.

This project has been identified as a required upgrade in prior Facilities Studies (OASIS request #74899988_89 and #74899996). If both of the prior transmission service requests (OASIS #74899988_89 and #74899996) and proposed upgrade is withdrawn, this customer would be responsible for this upgrade.

1.3 Required Redispatch:

To alleviate the following constraints, the following redispatch is required – Increment Lewis Creek generation by 205MW and decrement Entergy resources outside of WOTAB region. Lewis Creek reliability must run requirements to serve local area load must be adhered to throughout the entire year

Grimes-Bentwater 138kV FTLO Grimes-Mt. Zion-Huntsville 138kV

Mt. Zion-Huntsville 138kV FTLO Cypress-Hartburg 500kV

Cypress 500/138kV Auto FTLO Cypress 500/230kV Auto

Tubular-Dobbin 138kV FTLO Cypress-Hartburg 500kV


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1.4 CLECO Affected System Study

CLECO has been identified as an affected system. The customer will need to satisfy the requirements deemed necessary by CLECO.

1.5 Cost Summary

The estimated total project cost in 2011 dollars is $138,155,365. This cost does not include Tax Gross Up which may apply. Please note these are 2011 dollars and do not include tax gross-up if and where applicable (Tax Gross Up rate at this time is 24.21%). The ICT has assigned $42,210 as Base Case upgrades and $138,113,154 as Supplemental Upgrade based on Attachment T of Entergy’s Open Access Transmission Tariff (OATT).

1.6 Schedule Summary

The requested date for the start of network transfer is June 1, 2012. Based on the schedules developed for this study, this date will not be met. Based on Entergy project schedules, the upgrades will be completed by the end of December 2014.

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 to enable Entergy to prepare a PEP and be able to complete the project as per outlined in the schedule described provided below. It is not recommended that the project commence on the basis of only this document. Use of facility study and the associated estimates is not favored to commence an approved project. Estimates.

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 2011 dollars and are based on existing data and could change considerably after development of a detailed project execution plan. Price escalation for work in future years has not been included.

Relay settings and RTU configurations Details need to be specified during PEP stage, such as equipment and schemes for pilot protections.


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System changes will be modeled in ASPEN. Relay Impact Analysis will be performed by a settings engineer during PEP stage to identify requirements for relay/CT replacement and settings revisions at the local and remote stations in the area. For example, affected elements include Z2, Z3, ground overcurrent settings, and so on. Some obsolete relays may need to be replaced.

Communicate the project and protection coordination with nuclear, generation plants, load customers and other interconnected utilities as appropriate.

Comply with PRC-001, PRC-023 and relevant procedures, standards and guidelines as appropriate.

New RTU configurations or revisions will be necessary for stations where new equipment is installed or equipment replacement takes place. For example, there may be a need to map the additional points from a new or different relay.

4. SCOPE OF WORK

4.1 Upgrade the Toledo Bend-Leach 138kV transmission line.

The Toledo Bend-Leach 138kV transmission line needs to have a capacity of 170MVA or greater on all components.

Line Data

Existing Line Rating 143 MVA

Required Line Rating (Minimum)

179 MVA

Proposed Line Rating (based on Equipment to be installed)

211 MVA

Affected line length 2.3 mi

Line route:

Existing route – Line upgrade will follow existing corridor of L449 Toledo Bend to Leach Sub.

Structures and Foundations

The upgraded line from Toledo Bend to Leach will require the installation of approximately 21 new concrete poles. Direct-embedded concrete tangent structures and direct-embedded guyed concrete dead-ends will be used. The line will be in a delta configuration on the tangent structures and in a vertical configuration on the dead end structures.

This project will require the removal of approximately 21 wood structures.

Conductor and Insulators

The upgraded line from Toledo Bend to Leach will require the installation of approximately 75 insulator assemblies and the removal of approximately the same number of existing ones.


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The upgraded L-449 will require the installation of approximately 34,425 lbs of 666.6 kcmil ACSR “Flamingo” conductor and the removal of approximately 2.3 circuit miles of 395.2 ACAR conductor.

Shield Wire

OPGW wire will be used for shield wire. It will be terminated on splice boxes on the dead-end structure. Approximately 12,350 lbs of 48-fiber “Alumacore” OPGW will be used.

7#7 will be used as the shield wire on spans that require a second shield wire. Approximately 500’ will be installed.

ROW

The line is situated on Entergy’s ROW and no new ROW is required, therefore we would only need to inform the property owners before construction. The new line will be constructed on existing Entergy ROW adjacent to the existing line ROW. Subsequent to energization of the new line, the existing line will be removed from service, material disposed and ROW restored.

Environmental and regulatory Permitting:

Environmental concerns will include any associated NEPA issues for any federally connected projects, 404 and Section 10 permits and mitigation for wetlands and water bodies, state construction permits, CZM permitting issues within the affected coastal counties, environmental site assessment (for the substation site-Ph-1/Ph-2), avian friendly construction, any historical concerns (state SHPO), highway permits and floodplain permits. The PUCT needs to be notified 45 days before the start of construction pursuant to their exemption rules for CCN’s. They are notified via the monthly construction progress report that is filed each month.

Construction methodology: (See also section 5 assumptions by construction)

Assuming that the line can be taken out of service as planned for a minimum of 6 weeks, this section can be rebuilt in either of the shorter windows as proposed. Records indicate a couple of structures already replaced with single tangent (258 & 267) structures that should be considered for transfer to stores with transportation if suitable for reuse. Design is asked to use all self supporting structures, with no anchors or guys. This section is possible to use single pulls and reels to match due to short length and absence of severe bends, slightly longer than 2 miles and materials should be ordered accordingly to match.

Outage Planning:

A 6 – 8 week outage request is proposed, subject to further evaluation, well in advance of approval window.


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Safety consideration and risks during construction:

Follow all Entergy and OSHA rules including EPZ and Grounding requirements as well as clearance rules. 4.2 Toledo Bend 138kV Replace line bay bus:

Existing 138kV L-449 will be upgraded as necessary to ensure a capacity of at least 179MVA (749 Amps). The existing line bay bus at Toledo Bend (Leach line bay) needs to be replaced to meet the capacity. For reference see the one-line included with this document. This is customer owned substation and all work needs to be coordinated with the customer.

Site:

No work is required.

Foundations:

No work is required.

Electrical:

Existing 4/0 Cu. (559 amps) line bay bus will be replaced with 666 MCM ACSR (882 amps).

Relay:

OPGW will be installed on the reconstructed line in the shield position. It is assumed that the proposed change from 144MVA to 211MVA line capacity is not a concern for the existing relay protection scheme for the line and will not impact the performance and reliability of the SEL 221 & KD relaying scheme for L-449. A relay impact analysis is necessary to determine the full impact of the line rebuild.

Relay settings:

Revise line relay settings allowing line to carry the required increased MVA

Construction methodology: see also section 5 assumptions by construction.

Take line outage, remove bus, clamps and other hardware and replace it with new ACSR conductor during line rework outage. Assuming this work will take less than a week to complete and can be done easily by either AM crews or contractor during the line outage. AM Relay crews should be available to implement any relay changes during the line rework duration. Matting is required to traverse in any areas deemed as wetlands. Matting will also be required to cross any pipelines. The line will be staked and one call will be made in advance of construction. Any locations near pipelines or other underground utilities will be moved (with design’s approval) and re-marked or hydro probed.


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Outage Planning:

Book outage in TAOR well in advance


Insure proper isolation and grounding of line after it is taken out of service

Insure that the secondary side of the bus connected PTs (if any) have fuses removed to prevent back feeding of the bus.

4.3 Upgrade Newton Bulk-Leach 138kV transmission line.

The Toledo Bend-Leach 138kV transmission line needs to have a capacity of 177MVA or greater on all components.

Line Data

Existing Line Rating 143 MVA


177 MVA


211 MVA


Line route:

Existing route – Line upgrade will follow existing corridor of L449 Leach Sub to Newton Bulk.


The upgraded line from Toledo Bend to Leach will require the installation of approximately 254 new concrete poles. Direct-embedded concrete tangent structures and direct-embedded guyed concrete dead-ends will be used. The line will be in a delta configuration on the tangent structures and in a vertical configuration on the dead end structures.

This project will require the removal of approximately 254 wood structures.


The upgraded line will require the installation of approximately 783 insulator assemblies and the removal of approximately the same number of existing ones.

The upgraded L-449 will require the installation of approximately 372,680 lbs of 666. kcmil ACSR “Flamingo” conductor and the removal of approximately 24.9 circuit miles of 395.2 ACAR conductor.

Shield Wire



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ROW

The line is situated on Entergy’s ROW and no new ROW is required, therefore we would only need to inform the property owners before construction. The new line will be constructed on existing Entergy ROW adjacent to the existing line ROW. Subsequent to energization of the new line, the existing line will be removed from service, material disposed and ROW restored.

Environmental and regulatory Permitting:

Environmental concerns will include any associated NEPA issues for any federally connected projects, 404 and Section 10 permits and mitigation for wetlands and water bodies, state construction permits, CZM permitting issues within the affected coastal counties, environmental site assessment (for the substation site-Ph-1/Ph-2), avian friendly construction, any historical concerns (state SHPO), highway permits and floodplain permits. The PUCT needs to be notified 45 days before the start of construction pursuant to their exemption rules for CCN’s. They are notified via the monthly construction progress report that is filed each month.

Relay settings at Newton:

Revise line relay settings enabling line to carry the increased MVA as specified


Line construction of this longer portion of work will be undertaken as proposed with multiple crews, beginning on each end of the line. The work will be broken down into approximately 2 mile segments, with rebuild underway up to successive dead-end structures which would allow return of the line if necessary. This could be accomplished by field ties of both newly rebuilt and existing sections. Once the new conductor and structures are in place, wreck out of existing line could be undertaken most likely with the new circuit in service further reducing outage windows. This would be addressed during award or bid period with understanding of clearance issues. Matting is required to traverse in any areas deemed as wetlands. Matting will also be required to cross any pipelines. The line will be staked and one call will be made in advance of construction. Any locations near pipelines or other underground utilities will be moved (with design’s approval) and re-marked or hydro probed.


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Outage Planning:

Outages will be entered and taken as approved in proposed 12 week increments during favorable season weather, spring or fall as allowed and funded.


Parallel 500kV line will require extra attention to grounding and induced voltages. Follow all Entergy and OSHA rules including EPZ and Grounding requirements as well as clearance rules. 4.4 Grimes Substation

Add a third 345/138 kV 3 phase transformer with tertiary brought out for connecting reactors in future. The addition of this transformer requires the conversion of the existing 345kV ring bus into the folded breaker and a half bus scheme as per expansion plans to satisfy the requirements for ultimate equipment arrangement.

Site:

The existing site will be expanded on the east side for the new autotransformer and 345kV equipment approximately 150’ x 800’. The existing eastern fence (approx. 770’) will be removed and a new fence installed around the perimeter of the yard expansion on the east side. On the west side, a portion of the substation will be expanded. The approximate area of expansion will be 355’ (west) by 325’ (south) to facilitate the completion of the breaker and a half bay for autotransformer #2. Addition of another breaker and the extension of the north bus are required. The site expansion will require a significant amount of excavation, fill and limestone rock surfacing material. The southeast corner of the east site expansion will require as much as 10’ of fill material. An existing drainage ditch will have to be relocated to the east of the new expansion. The following site work required for this project included approximately:

Remove approximately 1,300’ of fence including existing access gate.

Install 1,800’ of new fence including a new access gate.

Clear, remove vegetation, and sterilize approximately 6 acres for development

Excavate and Grade 17,000 cyds of existing soil material

Install and compact 38,400 cyds of structural fill material

Dispose of 30,000 cyds of unused soil material

Install 7,500 tons of crushed rock for the substation pad

Install 4,900 tons of crushed rock for the road surface inside the substation

Relocate the drainage ditches around the affected area of the substation expansion

Install a new 27” RCP pipe at the access road crossing for drainage


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Environmental Requirements:

Based on the slope of the land and the location of water near the substation, there is no need for sized secondary containment. Instead, the requirement is to have gravel around the new oil filled equipment and for the existing well to be protected. Additionally, while construction is underway in this facility, requirement is to check the gravel around the existing oil filled equipment to make sure it is adequate (about 6 inches deep for at least 10 to 12 feet around the equipment).

Foundations:

The following foundation work is required for the addition of the new auto transformer:

Install 5- 345kV Breaker foundations

Install 1- 345/138/13.8kV 525MVA Autotransformer foundation with oil containment

Install 7 - 345kV CCVT foundations

Install 3 - 345kV 1 phase bus support foundations – high bus

Install 18 - 345kV 1 phase bus support foundations – low bus

Install 17 - 345kV 3 phase bus support foundations – high bus

Install 5 - 345kV 3 phase bus support foundations – low bus

Install 5 - 345kV switch support foundations – high bus

Install 7 - 345kV switch support foundations – low bus

Install 5 - 150’ static tower foundations

Install 1 – fire barrier wall foundation

Install 2- 345kV reduced tension dead-end foundations

Install 3 – 138kV Breaker foundations

Install 4 – 138kV switch support foundations – low bus

Install 1 – 138kV dead end @ auto (10AS52 type) foundation

Install 1 – 138kV dead end @ 138kV Bay 11 (add-on)

Install 750’ of pre-cast cable trench near the new 345kV breaker bay.

Install 18,500’ of ground grid in the expanded area (this includes the grid and the jumpers for the new equipment being installed as well as the fence expansion)

Install approximately 2,000’ of 4” PVC conduits from existing and new trench to new equipment.

Electrical:

The following foundation work is required for the addition of the new auto transformer:

Install 7 - 345kV CCVT pedestals.

Install 3 - 345kV 1 phase bus supports – high bus

Install 18 - 345kV 1 phase bus supports – low bus

Install 17 - 345kV 3 phase bus supports – high bus


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Install 5 - 345kV 3 phase bus supports – low bus

Install 5 - 345kV switch support steel – high bus

Install 7 - 345kV switch support steel – low bus (5 with insulator spacers)

Install 5- 345kV, 3000A, 40kA Gas Breakers

Install 1- 345/138/13.8kV 525MVA Autotransformer

Install 7 – 345kV CCVT’s

Install 5 – 345kV, 2000A GOAB switches, with motor operators on low bus (3 on existing steel and 2 on new steel)

Install 5 – 345kV, 2000A GOAB switches, with motor operators on high bus

Install 192 - 345kV post insulators (90 for switches and 102 on bus/switch supports/dead-ends)

Install 6 – 345kV suspension insulators at dead-ends for bundled 954 45/7 ACSR stung bus from 345kV switch to autotransformer

Install 6,500’ of rigid bus 5” schedule 80 EHV (954 45/7 ACSR damper

Install 7,500’ of strung bus Bundled 954 ACSR Bus, damper cable and jumpers.

Install 5 - 150’ static tower steel

Install 1 – fire barrier wall

Install 2- 345kV reduced tension dead-end structures

Remove 1 – 36MVAR, 138kV Capacitor bank and return to stores.

Install 3 – 138kV, 3000A, 40kA, Gas Breakers

Install 4 – 138kV switch support steel – low bus (2 with insulator spacers)

Install 1 – 138kV dead end @ auto (10AS52 type) structure

Install 1 – 138kV dead end @ 138kV Bay 11 (add-on)

Install 2 – 138kV, 2000A, GOAB switches on low switch steel (Note: spacing is 8’ center to center).

Install 30 – 138kV post insulators (18 for switches and 12 for buses/dead-ends)

Install 6 – 138kV polymer suspension insulators on dead-ends at 138kV bay 11 and at auto transformer 138kV dead-end.

Install 300’ of rigid 5” schedule 80 aluminum bus in 138kV bays (954 45/7 ACSR damper)

Connect ground grid jumpers to structures and equipment

Install 1,000’ of strung bus Bundled 954 45/7 ACSR from Auto transformer dead-end to T-Line pole outside south fence.(NOTE: Bundled 954 45/7 ACSR cable outside fence to bay 11 provided by T-Lines scope of work.

Relaying:

Control House General Equipment

Twenty one new panels will be required for this project. These new panels are to have the GSU wing wall design in order to be inserted into the existing protection rows. All blank or out of service panels in the control house must be removed in order to create enough floor space for the new panels and avoid expansion of the control house. Consult with Asset Maintenance to ensure Panel Layout is in the best ergonomic configuration.


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The existing battery charger #1 is a 50A model with 5.2A load, and the existing 440Ah battery set #1 is in good condition. It is estimated that no upgrades will be necessary for this battery set due to the added equipment.

The existing battery charger #2 is a 12A model with 1.8A load, with an existing 200Ah battery set #2. The DC load is not effectively divided between battery sets #1 and #2. All new equipment will divide DC load between battery sets #1 and #2. It is estimated that battery charger #2 and battery set #2 will not be adequate. Size, purchase and install one (1) 130V battery charger. Reference Entergy Standard PM0302, latest revision, for sizing guidelines. It is estimated that a 50A battery charger will be needed. Size, purchase and install one (1) 125VDC Lead Acid Battery sets including 2 step rack rated for a seismic zone 1, per Entergy Standard PM0203, latest revision. It is estimated that a 270Ah set will be required.

All AC panels in use in the control house are not adequate to support the installation of the other twenty additional panels. Purchase, design and install one (1) stand alone AC panel per Entergy Standard PM0101, latest revision.

There is an existing split DC panel serving DC system #1 and #2. It is estimated that this panel can be consolidated to serve DC system #1 and an additional one (1) DC stand alone panel will be purchased, designed and installed per Entergy Standard PM0101, latest revision to serve DC system #2.

The existing GE Harris D20 RTU ME board will be upgraded per Entergy standard PM3002, current revision. The RTU is installed inside a cabinet with standard terminations for analog and status points. It is estimated that (4) four additional D20S cards with standard terminals will be required. It is estimated that (2) two additional D20 KI2 cards with standard terminations will be required. At present, there are 2 K boards and 6 KI2 cards installed in the RTU. No additional K board will be required. However the cabinet appears maxed out and an additional cabinet is required for all new equipment. The existing cabinet and the new cabinet must be fitted with cabinet locks and mag-lock card readers installed for cyber security purposes.

Purchase and install (1) one cyber security cabinet containing a Gauntlet secure port switcher, one SEL 2407 satellite clock, one Starcomm modem model number 240-0199, one AC adapter, and all needed cables required for relay communications.

Purchase and install expansion equipment for the existing DFR.

345kV/138kV Autotransformer #3 Protection

Purchase, design and install one (1) Autotransformer Panel. The panel uses an ERL-phase T-Pro 8700 transformer differential relay for primary differential protection in a large differential zone. The protected zone will wrap from the bus side CTs of the 345kV breaker bushings to the bus/line node side CTs of the 138kV breaker bushings, including autotransformer neutral CT input. The panel uses a SEL 387-6 transformer differential relay for backup differential protection in a small differential zone. The protected zone wraps from the high side CTs of the autotransformer to the low side


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CTs of the autotransformer including neutral CT input. Provision for delta tertiary CT input is also made for future use.

Purchase, design and install one (1) Bus Differential Panel referencing Entergy standard PM0602, latest revision. This panel incorporates a SEL 487B relay for current differential protection. The protected zone will wrap from the high side 345kV CTs of the autotransformer to the bus side CTs of the 345kV circuit breakers. This bus differential panel will function as backup protection of the high side portion of the large zone autotransformer protection.

Purchase, design and install one (1) Bus Differential Panel referencing Entergy standard PM0602, latest revision. This panel incorporates a SEL 487B relay for current differential protection. The protected zone will wrap from the low side 138kV CTs of the autotransformer to the bus/line node side CTs of the 138kV circuit breakers. This bus differential panel will function as backup protection of the low side portion of the large zone autotransformer protection.

This scope assumes that the tertiary will included in the autotransformer but not bussed out. CTs must be provided on the tertiary for future use.

Install one (1) new 345kV CVT with carrier accessories per Entergy standard PN0201, latest revision. This CVT will be used for hot 345kV node indication, breaker synchronization, and MVA monitoring. All CVTs to be purchased with carrier accessories for coordination and ease of construction purposes.

Purchase and install one (1) single phase CVT junction box per Entergy Standard.


Install one (1) new 345kV CVT with Carrier accessories per Entergy standard PN0201, latest revision. This CVT will be used for hot 345kV node indication, breaker synchronization, and MVA monitoring. All CVTs to be purchased with carrier accessories for coordination and ease of construction purposes.


Reconfiguration of the 345kV station from ring to breaker and a half requires modification/change of all existing autotransformer #1 protection current inputs, potential inputs, and trip outputs. Care must be taken when requisitioning circuit breakers to avoid CT mismatch for PVD differential schemes.


Install one (1) new 345kV CVT with Carrier accessories per Entergy standard PN0201, latest revision. This CVT will be used for hot 345kV node indication, breaker synchronization, and MVA monitoring. All CVTs to be purchased with carrier accessories for coordination and ease of construction purposes.



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Reconfiguration of the 345kV station from ring to breaker and a half requires modification/change of all existing autotransformer #2 protection current inputs, potential inputs, and trip outputs. Care must be taken when requisitioning circuit breakers to avoid CT mismatch for PVD differential schemes.

Reconfiguration of the 138kV bay associated with autotransformer #2 to a double breaker double bus requires purchase, design and installation of one (1) Bus Differential Panel referencing Entergy standard PM0602, latest revision. This panel incorporates a SEL 487B relay for current differential protection. The protected zone will wrap from the low side 138kV CTs of the autotransformer to the bus side CTs of the 138kV circuit breakers. This bus differential panel will function as backup protection of the low side portion of the large zone autotransformer protection.

345kV Circuit Breaker Control

Purchase, design, and install five (5) EHV Breaker Control Panels referencing Entergy standard PM0501 option B, latest revision. The panel uses a SEL 451 relay for breaker control and protection. This panel will be used for protection and control of the 5 new 345kV circuit breakers.

Complete design of the AC and DC control schematics as well as the monitoring alarms for the 5 new 345kV circuit breakers will be required.

345kV North and South Bus Differentials

Purchase, design and install four (4) Bus Differential Panels referencing Entergy standard PM0602 options A & B, latest revision. The option A panel utilizes an ERL-phase B-Pro for current differential protection. The option B panel utilizes a SEL 487B relay for current differential protection. Each bus will be protected with a B-Pro relay and a SEL 487B relay for primary and backup bus differential protection.

Install six (6) new 345kV CVTs with Carrier accessories per Entergy standard PN0201, latest revision. These CVTs will be used for hot 345kV bus indication, and breaker synchronization. All CVTs to be purchased with carrier accessories for coordination and ease of construction purposes.

Purchase and install two (2) three phase outdoor potential junction boxes and two (2) indoor potential distribution boxes per Entergy Standard PM2402, latest revision.

138kV Circuit Breaker Control

Purchase, design, and install five (5) HV Breaker Control Panels referencing Entergy standard PM0501 option A, latest revision. The panel uses a SEL 351 relay for breaker control and protection. These panels will be used for protection and control of the 3 new 138kV circuit breakers, the repurposed capacitor bank breaker, and one of the two repurposed breakers previously associated with line 485.

Complete design of the AC and DC control schematics as well as the monitoring alarms for all affected/new 138kV circuit breakers will be required.


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138kV Mt. Zion Line 485 (Existing 138kV Line)

The existing primary and backup line relay panels as well as one of the breaker control panels associated with line 485 will be replaced with a new line/breaker control panel. The line relay communication scheme is a POTT/DTT1 and DTT2 application and will continue to transmit from Grimes in its present configuration. This requires the purchase, design and installation of one (1) Line/Breaker Control Panel configured for POTT/DTT1 and DTT2 application. This panel incorporates a SEL 421 relay for primary protection and an SEL model 311C for backup step distance relaying.

Install three (3) new 138kV CVTs with Carrier accessories per Entergy standard PN0201, latest revision. These CVTs will be used for hot 138kV line node indication, line relaying, and breaker synchronization. All CVTs to be purchased with carrier accessories for coordination and ease of construction purposes.

Purchase and install one (1) three phase outdoor potential junction box per Entergy Standard PM2402, latest revision.

Existing 138kV Equipment

Remove the following equipment from the 138kV substation yard including all associated equipment in the control house:

138kV capacitor bank and control panel

Motor operators on switches 16726 and 16619 and controls within the control house

Remove all existing control panel equipment for breakers 16630 and 16635.

Long Delivery Items:

Quantity Description Delivery time

5 345kV breaker 28-32 wks

3 138kV breaker 14-16 wks

1 345kV/138kV 525MVA autotransformer 26-32 months

10 345kV GOAB vertical Break switch 18-20 wks

2 138kV GOAB vertical Break switch 14-16 wks

Multiple 138kV & 345kV Steel 18-20 wks

192 345kV post insulators 11-14 wks

6 345kV suspension insulator 10-12 wks

30 138kV post insulators 11-14 wks

6 138kV suspension insulator 10-12 wks

10 motor operators 8-10 wks

Multiple Copper/Al cable & 5” sch 80 bus (standard & EHV)

10-14 wks

1 270Ah Battery Set 12-14wks

1 AC Panel 12-14wks

1 DC Panel 12-14wks

1 Line/Breaker control panel 12-14wks


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1 Cyber Security Cabinet 12-14wks

1 Autotransformer Diff Panel 12-14wks

7 Bus Diff Panel 12-14wks

9 345kV CVTs 20-22wks


10 Breaker Control Panel 12-14wks

Relay settings:

Grimes 345 KV:

Model new 345/138 kV, 525 MVA transformer (transformer #3) in Aspen Oneliner.

Provide relay settings for new Primary and Backup transformer differential relays for Transformer #3 (T-Pro and SEL387-6).

Provide relay settings for Autotransformer #3 Tertiary protection Panel (SEL-351).

Revise relay settings for Autotransformer #1 Differential and Tertiary panels (BDD16, BDD20, IAC, IAV).

Revise relay settings for Autotransformer #2 Differential and Tertiary panels (T-PRO, CEY, BDD).

Provide relay settings for Primary and Backup 345 kV Bus Differential relays for both the North and South bus – relays to be determined (4 sets of settings).

Provide relay settings for 5 new 345 kV breaker control panels (SEL451).

Revise Line relay settings for 345 kV L-120 Frontier line panel (LCB, SEL321).

Revise Line relay settings for 345 kV L-119 Crockett line panel (CEY, CEB, SLY, SLYG).

Review and revise Frontier Stability relaying after consultation with planning (SEL321).

Grimes 138 KV:

Model upgraded line 138 kV L-485 to Mt. Zion/Huntsville.

Provide new settings for 138 kV L-485 line relay panel (SEL421/SEL311C) using existing tone equipment.

Revise relay settings for 138 kV L-112 line relay panel (SEL421/SEL311C) to Conroe Bulk.

Revise relay settings for 138 kV L-94 line relay panel (SEL421/SEL311C) to Navasota.

Revise relay settings for 138 kV L490 line relay panel (CEY,CEB,JBCG) to Bryan.

Revise bus differential relay settings for 138 kV Bus #1 (East Bus)(PVD).

Revise bus differential relay settings for 138 kV Bus #2 (West Bus) (B-PRO).

Provide relay settings for 5 new 138 kV breaker control panels.


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Bryan 138 KV:

Revise relay settings for 138 kV L-490 line relay panel (SEL421, KD, KRD, IRD).

Conroe Bulk 138 KV:

Revise relay settings for 138 kV L-112 line relay panel (KD4, IRD81). Huntsville 138 KV:

Revise relay settings for 138 kV L-485 line relay panel (CEY, CEB, JBCG). Navasota 138 KV:

Revise relay settings for 138 kV L-94 line relay panel (KD4, IRD81).

REMOTE STATION REVISIONS:

Due to fault current increases caused by the addition of the third Auto-transformer at Grimes, revisions of ground over current relaying at 14 remote terminals will need to be reviewed and revised: Bryan – Pee Dee, Pee Dee – Bryan, Rivtrin – Pee Dee, Pee Dee – Rivtrin, Huntsville – Rivtrin, Rivtrin – Huntsville, Navasota – College Station, College Station – Navasota, College Station – Bryan, Bryan – College Station, Navasota – Longmire, Longmire – Navasota, Longmire – Lewis Creek, Lewis Creek – Longmire Should any of these relays are not settable, replacement will be required (not included in the estimates as more detailed work has to be done in setting these relays before a decision can be made)

RTU configuration:

Required configuration for alarms, status, metering and control of breakers, switches and tap changer will be prepared based on edit sheets supplied by relay design. Relay design will ensure that the hardware and latest edit sheets are available to apply the new configuration.

Construction methodology:

A SWPPP plan will be required and Implemented before construction begins. All site, foundation, and steel and electrical work will be bid and contracted out. Site work will take place to physically expand the size of the Grimes substation. A new drainage ditch will be dug to match up to the existing drainage. The dirt excavated will be used as fill for the substation expansion. Fill and rock will be brought in for the yard to meet final grade. Approximately 1,300’ of fence and a gate will be taken down and replaced with approximately 1,800’ of fence and a new access gate as part of the site expansion. New foundations will be poured including 4 – 345kV breaker foundations and one autotransformer foundation. All foundations will be poured, and then the ground grid and grounding tails will be placed in the ground. All conduit runs will be trenched in and then the site will be filled back in and compacted to final compaction and grade. After the foundations have had proper curing time, the steel


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will be erected. The breakers will be set and the transformer will be brought in. The transformer is being brought in from a rail spur approximately four miles away. A contractor will be hired to transport the transformer from the rail car to the substation and set it on the pad. The route the transformer must take to arrive at the station is a county dirt road with overhanging trees. The road also has a wooden bridge and a low water crossing that will require matting and special ramp to be able to safely cross them. After all steel and electrical equipment has been installed; a relay crew will install panels, terminate, apply settings, and test circuits. Much of the new addition of 345kV bus can be done without an outage requirement. Two breakers can be installed as well as the switches around the breakers. The 3rd transformer and the high side switch can be installed without an outage either. The bus to connect these devises together can also be installed as “green field.” Not all of the new North side bus can be installed. It will be installed up to just before it crosses the South side bus. The first outage required will be to take out the South bus. This will allow the new North bus to be built to cross over the South bus. During this outage the new South bus will be connected, 2 CCVTs will be installed, 1 new 345kV GCB and 2 new 345kV switches will be installed. A new 138kV breaker between switches 16727 and 16638 will be installed and the CTs will be tied into the new bus panels. Also the T2 relaying will be reconfigured during this first outage. The second outage will de-energize the North Bus allowing the new North Bus to be tied in. This second outage will also involve installing a new 345kV GCB and one 345kV switch. During this time 2 CCVTs will be installed and the CTs will be tied in to the new bus panels. T1 relaying will be reconfigured to complete the second outage. The third outage is flexible in timeframe and is a localized outage. Breaker 26010 will be de-energized to create the third outage. The cap bank will be removed and new bus will be installed to connect switch #16729 to GCB 26010, and a new CCVT will also be installed. The fourth outage is L485 outage and will mainly be used for line work but it must coordinate with the substation outages. During the fourth outage an A frame line terminal will be installed for the new L485 to connect to between switches 16632 and 16633. L485 will be relocated to the new GCB terminal. This outage will overlap outage 5. Finally a fifth outage will be required to take out the East bus. During this outage the old L485 conductor that runs over the bus to the first lattice tower will be removed. The new L485 conductor will be installed conductor over the bus. The new T3 conductor will be installed over the bus, and the 138kV bus scheme will be reconfigured for the new breakers. This outage will overlap the fourth outage as well as be in conjunction with the first outage for T2 relaying. Remote station revisions – If the setting revisions can not be accomplished, replacement of relays will be required. Till such time the analysis is done it is not possible to identify the number of relays requiring replacement or only requiring setting changes. Hence the estimate can not be provided at this time.

Outage requirements and durations for Grimes Substation:

Multiple outages will be needed to complete the Grimes and L485 upgrade.

The first outage will be 5 weeks in duration and will open the South Bus at Grimes – devices 16800, 26175, and T2.


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The second outage will be 3 weeks in duration and will de-energize the North Bus at Grimes – devices 26170, 26180, and T1.

The third outage is a local device outage on breaker #26010 with duration of one week.

The fourth outage is L485 Grimes to Mt Zion with duration of 3 weeks.

The fifth outage is for the East bus at Grimes and is 2 weeks in duration.

Outage 1, 4, and 5 all must coordinate together. Construction will utilize Utility Ops Grid Relay personnel or a contract relay crew to perform required relay setting changes. They will travel to each station and upload new settings. 4.5 Mt Zion to Grimes 138 kV new line

The Mt Zion to Grimes 138 kV needs to have a capacity of 250 MVA or greater on all components.

Line Data


250 MVA


260 MVA


Line route:

Due to lack of outage to re-conductor existing line, a new line will be constructed on existing Entergy ROW adjacent to the existing line ROW. Subsequent to energization of the new line, the existing line will be removed from service, material disposed and ROW restored.


The upgraded line from Mt. Zion to Grimes will require the installation of approximately 155 new concrete poles and 18 steel poles. Self-supporting steel dead-ends in steel foundations and direct-embedded steel tangent structures are used inside Grimes Substation. Direct-embedded guyed concrete dead-ends and running angle structures and direct-embedded tangents are used in most locations between Mt. Zion and Grimes, with the exception of one 11 span section where ground conditions appeared to be wet. In the wet section, steel poles in steel caissons are assumed. The line will be in a delta configuration on the tangent structures and in a vertical configuration on the dead end and running angle structures. It will be in a horizontal configuration for one span where it crosses under 345kV L-120.

Line Relocation at Grimes - The 138kV connection line between Autotransformer #3 and Bay 10 at Grimes substation will require the installation of two 3-pole self-supporting dead-end structures in steel foundations.


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This project will require the removal of approximately 345 wood poles, 155 cross-arms, 50 guy wires and 50 anchors.


The upgraded line from Mt. Zion to Grimes will require the installation of approximately 564 insulator assemblies and the removal of approximately the same number of existing ones.

The 138kV connection line between Autotransformer #3 and Bay 10 at Grimes substation will require the installation of 18 new insulator assemblies.

The upgraded L-485 will require the installation of approximately 393,000 lbs of 954 kcmil ACSR “Cardinal” conductor and the removal of approximately 19.2 circuit miles of 649 ACAR conductor.

The 138kV Autotransformer #3 to Bay 10 connection will require the installation of approximately 7,500 lbs of 2-bundled 954 kcmil ACSR “Cardinal” conductor.

Shield Wire

OPGW wire will be used for shield wire. It will be terminated on splice boxes on the dead-end structure. The project does not require extension of the OPGW in substations via use of ADSS cables through conduits or connecting to any communication equipment. Approximately 108,000 lbs of 48-fiber “Alumacore” OPGW will be used. 7#7 will be used as the shield wire on spans that require a second shield wire.

7#7 will be used as the shield wire for the 138kV connection between Autotransformer #3 and Bay 10. Approximately 2,000’ will be installed.

ROW

The line is situated on Entergy’s ROW and no new ROW is required. 60’ of existing ROW is available in the corridor that includes the existing L-485.

Environmental Permits

The upgrade of L-485 will require the design, installation, and monitoring of a Storm water Pollution Prevention Plan. For the purposes of completing this Facility Study, it has been assumed that three Railroad Crossings Permits and three Highway Crossing Permits will be needed. Although the actual number is unknown, that is a reasonable assumption for a line of this length Present assessment indicates no requirement for CCN build L-485 in existing ROW. If new ROW is needed, then it would trigger a CCN. Eleven creek crossings are known to exit on the line route that could potentially be wetlands. Wetlands delineation and permitting assistance for Nationwide 12 with a PCN (Pre-construction Notification) to the USACE will be required.


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Vegetation Management and Tree removal

For a section approximately 5 miles in length between Mt. Zion and where L-119 joins L-485 in the ROW, about 10 feet of the existing ROW will need to be cleared of vegetation to provide clearance for the new Transmission Line.


Quantity Material Description *Lead Time (weeks)

155 Poles, Concrete 10 weeks

24 Poles, Steel 18 weeks

393,000 Conductor, 954 kcmil ACSR “Cardinal” 22 weeks

108,000 Cable, OPGW, 48-Fiber Alumacore 16 weeks

582 Insulator Assemblies 14 weeks


Storm water mitigation controls will be installed in accordance with the SWPPP. The line work will be a bid job and contracted out. There is some vegetation removal to reclaim the ROW and this work will be bid and contracted out as well. The clearing/vegetation removal is approximately 10’ wide and runs from structure #100 to structure #145. There is also a pole barn and a storage container that has encroached on the ROW and a ROW agent will need to investigate these areas. The clearing can start at the same time as line work or ahead of time. The new L485 will be built next to the existing L485 within the same ROW. From structure #100 to structure # 205 can be built as green field without an outage requirement. There are some distribution crossings as well as FM road crossings. These locations will be guarded/covered-up and appropriate hot line holds or one-shots will be requested. The previous outage 4 mentioned in the substation section applies here as well. During outage 4 new conductors will be installed between the first and second lattice tower outside of Grimes substation, and the new L485 will be tied from dead end structure #205 into the new GCB line terminal. On the Mt Zion end of the line, the old line will be removed and the new L485 will be tied in from Structure #100 to the Mt Zion substation. After the new line is energized, wreck out of the old L485 from Grimes to Mt Zion will be completed. Matting is required to traverse in any areas deemed as wetlands. Matting will also be required to cross any pipelines. The line will be staked and one call will be made in advance of construction. Any locations near pipelines or other underground utilities will be moved (with design’s approval) and re-marked or hydro probed.

Outage Planning:

Outage requirements and durations for removing connection and make connection of new line at Grimes and Mt. Zion Substations:

Mt Zion is a customer owned station and coordination with the customer must take place to determine if upgrades are needed within Mt Zion’s substation as well as outage requests or one shot requests if needed.


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Outage 4 is L485 from Grimes to Mt Zion a three weeks in duration, same as outage above.

Removal of existing line, disposal of material and restoring ROW:

After the new line is energized, wreck out of the old L485 from Grimes to Mt Zion will be completed. The existing line is wooden structures, so the poles will be checked for MITC Fume treatments and the proper mode of disposal will be determined. There are approximately 11 locations that could be considered wetlands, and care must be taken in these areas. 4.6 New Substation (NSS) – 230 kV:

Build a new 230kV five terminal substation in Texas by undertaking the following:

Re-route the McLewis-Helbig 230kV transmission line (L-195) into the new five breaker ring bus switchyard; connecting the McLewis and Helbig 230kV substations to the new switchyard

Re-route the Sabine-Georgetown 230kV transmission line (L-572) into the new five breaker ring bus switchyard; connecting the Sabine and Georgetown 230kV substations to the new switchyard

New breakers at the New Substation need to have an interrupting rating of at least 27kA. Require at least 3000A, 40kA IPO breakers.

63KA IPO breakers will be used since costs are the same with breaker manufacturer

ROW requirements:

New substation site (900’X600’) would be located northerly and adjacent to the ROW intersection of Lines# 195/#572, the connecting ROW segment would be minimal, approximately 200’ in width and 200’ in length. New substation would be approximately 17 miles from Helbig Substation and 2.5 miles from McLewis Substation.

Environmental Permitting:

Wetlands delineation will need to be performed and a permit application submitted to the USACE. In addition, it is assumed that the entire new substation along with line cut-ins will require mitigation. A SWPPP will be required for the entire project area. Soil sampling will be required in order to allow for disposal of any dirt that may be removed from the site. Permitting and SWPPP preparation will need to be worked in conjunction with current site permitting and SWPPP plan. Wetland delineation and permitting will include both substation and line work.


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General Info

The New Substation, NSS, will initially be designed as a 5 element ring bus expandable to a 4 bay breaker and a half scheme. The switchyard will be orientated such that the lines will be entering the North West and South East sides of the substation; the control house will be located in the South center of the yard. Transmission lines entering the switchyard will be from both sides of the substation as shown on the electrical arrangement drawing - GXXXXEA1.

Assumptions:

Site location is the proposed primary site which facilitates T-Line entry from both sides of the substation.

The switchyard ground grid is designed for 40kA fault currents and 63kA breakers are not required – IPO breakers are required - 63kA breakers will be used since the costs are the same as the 50kA breakers.

Substation bus is rated 4500A (6” Sch 40 Aluminum Tubing) for both the West and East bus and 3000A (4” Sch 40 and bundled 1590 ACSR (45/7) conductors) for each bay of the ring.

Soil Resistivity is such that a standard 40’ x 40’ ground grid is sufficient.

There are no environmental wetlands involved.

Road Access is available.

NEW 230kV SUBSTATION PROPOSED SITE LOCATION

The proposed new 230kV substation site is located on the northern side of the R.O.W. intersection of Line No. 195 and Line No. 572. The size of this property is


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large enough to fit the proposed 365’ x 300’ substation (fence dimensions) plus additional space outside of the substation fence in order to route the new applicable transmission lines. A topographic survey has not been performed at the time of this study. However, a preliminary review of the topography of the property has determined that the property is relatively flat (< 2’ of change in elevation across the property). The eastern edge of the property contains a creek that is potentially susceptible to flooding.

Site Work

The Site Preparation Work is within existing property owned by Entergy and shall include the furnishing of all labor, material, transportation, tools, utilities, equipment, appurtenances, and performance of all operations necessary for filling and grading for the development of a 365’ x 300’ substation with finish grade elevation at least 3’ above existing grade. The purpose of raising the site 3’ allows for adequate fill cover above the subsurface drainage pipes. Raising the substation pad 3’ above existing grade is assumed to maintain the substation above the design 100 year flood elevation for the area. The substation yard and exterior access road will be surfaced with crushed rock. The site shall required an estimated 20’ wide x 1,000’ long access road entering from the nearest accessible public roadway. The Site shall be built in accordance with the Site Package Design drawings and the following Entergy Standards:

o SL 1201, Ground Covering and Access Road Design Guidelines o SL 1202, Substation Site Preparation (Earthwork) Standard o SL 1204, Initial Treatment and Control for Vegetation Management o SL 0701, Chain Link Substation Fence Design Specifications o SL 1301, Entergy Substation & Switchyard Signs Standards o SL 1302, Substation Sign & Roadway Marker Application Guide

Site grading installation recommendation specified in the Geotechnical Soils Report shall also form part of the installation requirement. A Geotechnical Soils report was not available at the time of this study.

The following site work required for this project included:

Clear, remove vegetation, and sterilize approximately 4 acres for development

Excavate and Grade approximately 3,000 cyds of existing soil material

Install and compact approximately 25,000 cyds of structural fill material

Dispose of 6,000 cyds of unused soil material

Install approximately 4,300 tons of crushed rock for the substation pad

Install approximately 1,300 tons of crushed rock for the road surface inside the substation.

Install approximately 1,400 tons of crushed rock for the road surface outside the substation

Install approximately 12 Catch Basins and 1,000’ of Sub-subsurface drainage

Install approximately 1,330 linear feet of substation fence.


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Foundation Work

Foundation Work will include installation of the following:

2 – Pull Boxes on 1 side of the control house

450’ Cable Trough (including 2-30’ road crossings)

1,500’ - Conduit Trenches with approximately 2600’ of 2” PVC Conduits

8,000’ - 4/0 copper ground grid (assumes 40’ x 40’ grid)

4,000’- 19 #9 Copperweld pigtails (200 @ an average length of 20’)

1 – 20’ x 40’ Control House foundation

5 – 230kV, 60’ A-frame Dead-end foundations (4 legs/ dead-end)

24 – 230kV, 1 phase Bus Support (Low Bus) foundations

6 – 230kV, 1 phase Bus Support (Hi Bus) foundations

18 – 230kV, Switch Support (Low Bus) foundations (2 legs/ support)

15 – 230kV, CCVT Support Pedestal foundations

15 – 230kV, LA Support Pedestal foundations

5 – 230kV, IPO Breaker foundations

2 – 230kV, 100KVA SSVT foundations

9 – Yard Lighting foundations

Electrical Work

Electrical Work will include installation of the following:

1 – 20’ x 40’ Control House

3,300’ Strain Bus (Bundled 1590 ACSR (45/7) for Breaker jumpers and Line Taps)

2,500’ – 4” Aluminum Tubular Bus Schedule 40 (for Bays, risers and line taps)

1,100’ – 6” Aluminum Tubular Bus Schedule 40 (for East and West buses)

5 – 230kV, 60’ A-frame Dead-end

24 – 230kV, 1 phase Bus Support (Low Bus)

6 – 230kV, 1 phase Bus Support (Hi Bus)

18 – 230kV, Switch Support (Low Bus – 1 with BK1 brackets for insulators)

15 – 230kV, CCVT Support Pedestal

15 – 230kV, LA Support Pedestal

2 – 230kV, 100KVA SSVT Support structures

2 – 230kV, 100KVA SSVT’s

5 – 230kV, 3000A, 63kA, IPO Breaker

12 – 230kV, 3000A, GOAB Switch

5 – 230kV, 2000A, GOAB Switch w/Ground Switch

15 – 230kV, CCVT’s (purchased by relaying)

15 – 230kV, Surge Arresters

9 – 2 fixture, HPS Yard Lights

153 – 230kV porcelain post insulators for switches

63 – 230kV High strength polymer insulators for bus supports and dead-ends.(30 for 1 ph bus supports, 3 for switch stand, 30 for dead end structures)

2 - 240/120 V, 400A fusible safety switches.


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Long Lead Items:

Qty Item Lead Time

450’ Cable Trough 8-10 weeks

2,500’ 4” Aluminum Tubular Bus Schedule 40 10-12 weeks


2 Pull Boxes

1 20’ x 40’ Control House 14-16 weeks

5 230kV, 60’ H-frame Dead-end 20-24 weeks

24 230kV, 1 phase Bus Support (Low Bus Structure 10-12 weeks

6 230kV, 1 phase Bus Support (Hi Bus) Structure 10-12 weeks

18 230kV, Switch Support (Low Bus) Structure(1 with BK1 brackets)

10-12 weeks

15 230kV, CCVT Support Pedestal Structure 10-12 weeks

15 230kV, LA Support Pedestal Structure 10-12 weeks

2 230kV, 100KVA SSVT Support structures 16-18 weeks

2 230kV, 100KVA SSVT’s 24-28 weeks

5 230kV, 3000A, 63kA, IPO Breaker 14-16 weeks

12 230kV, 3000A, GOAB Switch 14-16 weeks

5 230kV, 3000A, GOAB Switch w/Ground Switch 14-16 weeks

15 230kV, CCVT’s (purchased by relaying) 18-29 weeks

15 230kV, Surge Arresters 14-16 weeks

63 230kV, Insulator, Polymer 10-12 weeks

153 230kV, Insulator, Porcelain 10-12 weeks

2 240/120 V, 400 A Fused Safety Switches 11-14 weeks

Relay:

Size, purchase and install two (2) 125VDC Lead Acid Battery sets including 2 step rack rated for a seismic zone 1. It is estimated that a 200Ah sets will be required. Reference Entergy Standard PM020300.

Size, purchase and install two (2) 130V battery chargers. Reference Entergy Standard - PM0302, latest revision, for sizing guidelines. It is estimated that a 25A battery charger will be needed.

Purchase, design and install two (2) battery switch panels per Entergy Standard PN0103, latest revision.

Perform battery sizing assessment to confirm battery and DC equipment requirements.

Purchase and install one (1) AC switching panel (flip flop).

Purchase, design and install one (1) stand alone AC panel per Entergy Standard PM0101, latest revision.

Purchase, design and install two (2) stand alone DC panels per Entergy Standard PM0101, latest revision.

Size, purchase and install one (1) GE Harris D400S Remote Terminal Unit per Entergy Standard.

Telecommunication equipment will be needed for installation of one (1) TOC data circuit, one (1) POTS voice circuit, and all required relay communication circuits.


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Telecommunication equipment will include digital microwave via the Liberty/Pearl hub and backbone/T-line OPGW fiber.

Purchase, design and install one (1) line relay/breaker control panel using SEL Mirrored Bits over digital circuits for primary relaying communication referencing Entergy standard PM1803, option B, latest revision. This panel incorporates a SEL 421 relay for primary protection and an SEL model 311C for backup distance protection. This panel will interface with the L-572”a” SEL 421 primary relay at Sabine 230kV substation.

Establish protective relay telecommunications circuits between Sabine and NSS for portion “a” of line 572. This study assumes the circuits will be a combination of digital microwave via the Liberty/Pearl hub and backbone/T-line OPGW fiber.

Purchase, design and install one (1) line relay/breaker control panel using SEL Mirrored Bits over digital circuits for primary relaying communication referencing Entergy standard PM1803, option B, latest revision. This panel incorporates a SEL 421 relay for primary protection and an SEL model 311C for backup distance protection. This panel will interface with the L-572”b” SEL 421 primary relay at Georgetown 230kV substation.

Establish protective relay telecommunications circuits between Georgetown and NSS for portion “b” of line 572. This study assumes the circuits will be digital microwave via the Liberty/Pearl hub.

Purchase, design and install one (1) line relay/breaker control panel using SEL Mirrored Bits over digital circuits for primary relaying communication referencing Entergy standard PM1803, option B, latest revision. This panel incorporates a SEL 421 relay for primary protection and an SEL model 311C for backup distance protection. This panel will interface with a new L-195”a” SEL 421 primary relay at the Helbig substation.

Establish protective relay telecommunications circuits between Helbig and NSS for portion “a” of line 195. This study assumes the circuits will be digital microwave via the Liberty/Pearl hub.

Purchase, design and install one (1) line relay/breaker control panel using SEL Mirrored Bits over digital circuits for primary relaying communication referencing Entergy standard PM1803, option B, latest revision. This panel incorporates a SEL 421 relay for primary 1 protection and an SEL model 311C for primary 2 protection. This panel will interface with a new L-195”b” SEL 421 primary relay at the Hartburg substation.

Establish protective relay telecommunications circuits between Hartburg and NSS for portion “b” of line 195. This study assumes the circuits will be a redundant system of digital microwave and backbone/T-line OPGW fiber via the Liberty/Pearl hub and direct fiber via the new 230kV line to Hartburg.

Purchase, design and install one (1) line relay/breaker control panel using SEL Mirrored Bits over digital circuits for primary relaying communication referencing Entergy standard PM1803, option B, latest revision. This panel incorporates a SEL 421 relay for primary 1 protection and an SEL model 311C for primary 2 protection. This panel will interface with a new line SEL 421 primary relay at the Hartburg substation.

Establish protective relay telecommunications circuits between Hartburg and NSS for the new line. This study assumes the circuits will be a redundant system of


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digital microwave and backbone/T-line OPGW fiber via the Liberty/Pearl hub and direct fiber via the new 230kV Line to Hartburg.

Install fifteen (15) new 230kV CVT with Carrier accessories per Entergy standard PN0201, latest revision. All CVTs are to be purchased with carrier accessories for coordination and ease of construction purposes.

Purchase and install five (5) three phase potential junction boxes per Entergy Standard.

Long Lead Items:


2 125VDC Battery Set 12-14wks

1 AC Panel 12-14wks

2 DC Panel 12-14wks


1 RTU 12-14wks

1 Digital microwave equipment 20-22wks


Relay settings:

Develop relay settings for all lines and breakers at new SS

RTU Configuration:

Develop RTU configuration and program TOC master for display of status and control of apparatus at New SS


Storm water mitigation controls will be installed in accordance with the SWPPP. Matting is required to traverse in any areas deemed as wetlands. Matting will also be required to cross any pipelines for access. Build new substation once funded and materials are available from ground up using preferred/alliance contractors or competitive bid process. Assumed that the duration of substation work to be approximately 4 months with an additional month of checkout and commissioning of new line terminals. AM relay or contract relay crews to be used for wiring, testing and commissioning phases of substation work. Crew durations are assumed to be approximately 2 months, both at end of substation work and final month of checkout.

Outage Planning:

None required for substation work, line 195 and 572 cut-ins only. 4.7 Hartburg Substation – 500/230 kV:

Install new 800MVA, 500/230kV autotransformer


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Construct Hartburg 230kV ring bus and expand Hartburg 500kV bus to accommodate new transformer bay.

Single phase units are to be installed so that the spare for the existing auto can be used for the new auto.

New auto is to be sized similar to the existing auto (800MVA).

No reactive compensation is required for the tertiary. However, units will have a tertiary winding for future reactor applications

New breakers at Hartburg 230kV need to have an interrupting rating of at least 23kA. Require at least 3000A, 40kA IPO breakers.

New breakers at Hartburg 500kV need to have an interrupting rating of at least 25kA. Require at least 3000A, 40kA IPO breakers.

Environmental Permitting:

Wetlands delineation will need to be performed and a permit application submitted to the USACE. In addition, it is assumed that the entire new substation along with line cut-ins will require mitigation. A SWPPP will be required for the entire project area. Soil sampling will be required in order to allow for disposal of any dirt that may be removed from the site. Permitting and SWPPP preparation will need to be worked in conjunction with current site permitting and SWPPP plan. Wetland delineation and permitting will include both substation and line work.

230kV Ring Bus Area

A new 230kV transmission line termination point will be installed in the existing 230kV switchyard at Hartburg Substation. This will be accomplished by transforming the existing 230kV Substation area into a four breaker ring bus configuration (area is configured to be a breaker and a half scheme). The existing Helbig transmission line and 500/230kV #2 autotransformer will occupy two of the nodes of the new ring bus and the new NSS Substation transmission line and the new #1 autotransformer will occupy the other 2 nodes. Existing structures will be used where appropriate. Existing circuit breaker #13720 will be removed to accommodate the new configuration.

Assumptions:

It is assumed that the existing ground grid is adequate for the new construction and can accommodate the required 47kA fault rating. If deemed appropriate, a ground grid analysis will be performed during detailed design to confirm this assumption.

Existing North and South buses are sufficiently sized and do not need to be upgraded. (Note: current bus is 4” Schedule 40 Aluminum)


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An SSVT is not required for the new autotransformer and ring bus to run all of the associated auxiliary equipment (i.e. fans, heaters, breaker controls, batteries, etc) and the existing station service is sized for both autos since there was originally a second auto at Hartburg.

There is room in the existing cable troughs to install the new cables and no new “main” troughs are required; branch troughs are required.

There is enough room in the existing control house for the required relaying equipment.

Existing overhead lines from the ring bus area to the autotransformer area is still intact and does not need to be replaced.

Existing reactors that are located by the proposed autotransformer #1 and are currently used for the existing autotransformer #2 will remain as is and will not be moved/relocated. New autotransformer #1’s tertiary windings will not be used but will be available for future use.

Civil This is an existing site and no expansion of the substation will be required. Areas that are impacted by foundation work will be re-graded with new crushed rock. Approximate size of each construction area is 200’ x 360’. An estimated 5000 tons of limestone will be required.

Foundation All new structures will be tied to the existing grid with 19#9 copperweld conductor as per Entergy grounding standards.

Foundation Work will include installation of the following:

4 - 230kV circuit breaker foundation MM1 - as per drawing G1167F12

4 - 230kV switch support foundation per new tubular switch structure design (16’ spacing)

o (NOTE: each switch support foundation consists of two separate footings)

9 - 230kV single phase bus support foundation (new tubular design)

7 - 230kV CVT support foundation (new tubular design)

6 - 230kV station class surge arrester foundations

1 - 230kV A-frame dead end using 16’ spacing o (NOTE: each dead end foundation consists of four separate

footings)

45 – 19#9 copperweld “pigtails for structures and equipment – estimated qty @ 30’ per pigtail – 1,350’ total)

230 feet of pre-cast cable trough near northeast bay of ring bus

1,000’ of new 2” conduits (280’ for the 7 new CCVT’s and 720’ for the 4 breakers - 6 new conduits per breaker averaging 30’ ea)

1,120’ of conduit trench for above conduits

2,500 tons limestone surfacing for ring bus area (200’ x 360’)


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Electrical Work Electrical Work will include installation of the following:

1,200’ Strain Bus (Bundled 1590 ACSR (45/7) for Breaker jumpers and Line Taps)

2,500’ – 4” Aluminum Tubular Bus Schedule 40 (for Bays, risers and line taps)

1 - 230kV A-frame dead end structure (could be H-frame)

4 - 230kV 3000A, 63kA, IPO breakers

(NOTE: existing switch structures have 12’ spacing while new structures are 16’ spacing)

4 - 230kV switch supports low bus (new design - 16’ spacing)

5 - 230kV 3000A vertical break disconnect switches with 12’ spacing on existing structures (Note: existing line has a ground switch already installed)

o NOTE: center break switches may be required

4- 230kV 3000A vertical break disconnect switches with 16’ spacing (1 w/ground switch for the new line)

o NOTE: center break switches may be required

6 - 230kV surge arresters structures (new tubular design)

6 - 230kV station class surge arresters

7 - 230kV CVT support structures (new tubular design)

7 - 230kV CVT

9 - 230kV single phase bus supports (new tubular design)

81 – 230kV porcelain post insulators for switches

27 – 230kV polymer insulators for the bus supports and dead ends

Long Lead Items:

Qty Item Lead Time

230’ Cable Trough 8-10 weeks


1 230kV, 60’ A-frame Dead-end 20-24 weeks

9 230kV, 1 phase Bus Support (Low Bus) Structure 10-12 weeks

4 230kV, Switch Support (Low Bus) Structure 10-12 weeks

7 230kV, CCVT Support Pedestal Structure 10-12 weeks

6 230kV, LA Support Pedestal Structure 10-12 weeks

4 230kV, 3000A, 63kA, IPO Breaker 14-16 weeks

8 230kV, 3000A, GOAB Switch 14-16 weeks

1 230kV, 3000A, GOAB Switch w/Ground Switch 14-16 weeks

7 230kV, CCVT’s (purchased by relaying) 18-29 weeks

6 230kV, Surge Arresters 14-16 weeks

27 230kV, Insulator, Polymer 10-12 weeks

81 230kV, Insulator, Porcelain 10-12 weeks


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500kV/230kV Autotransformer Area

The location for the new autotransformers is actually to be located where a previous set of autos were abandoned. Site photos show existing bus work for 500kV, 230kV and tertiary buses. The tertiary bus is being used for reactors located at the new autotransformer location. They are currently being used for the existing autotransformer #2. A 4th pad and 3rd barrier will be installed to allow for the relocation of the existing spare if needed. A containment wall will be installed around the perimeter of the 4 pads.

Assumptions:

Oil containment is required and the existing autotransformer foundations will have to be modified along with the existing barriers.

Existing abandoned bus work and associated structures are intact and useable.

Strain bus from the 230kV dead-end to the individual single phase autotransformer dead-ends are intact and useable.

Foundation Work Foundation Work will include installation of the following:

4 - 500kV/230kV/13.8kV single phase autotransformer foundations w/containment and barriers (modify existing 3 and install new foundation for spare use – barrier around perimeter for containment and 1 barrier wall to isolate spare)

1 - 500kV IPO breaker foundations, 3000A, 63kA

2 - 500kV, 3000A, GOAB, vertical break switch foundations

3 - 500kV CVT support foundations

4 - 500kV surge arrester support foundations

4 - 230kV surge arrester support foundations

2,000’ of new 2” conduits for 500kV CVTs, Breaker, Motor operators and autotransformers)

750’ of conduit trench for above conduits

60 – 19#9 copperweld “pigtails for structures and equipment – estimated qty @ 30’ per pigtail – 1800’ total)

2,500 tons of limestone surfacing for autotransformer rework area (200’ x 360’)

Electrical Work Electrical Work will include installation of the following:

3 - 500kV/230kV/13.8kV single phase autotransformers, 160/212/267MVA (wye w/ delta tertiary)

1 - 500kV IPO breaker foundations, 3000A, 63kA

2 - 500kV, 3000A, GOAB vertical break, with 125VDC motor operator


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22 – 500kV porcelain post insulators for switches and autotransformer bus

1,200’ Strain Bus Tri-Bundled 954 ACSR (45/7) for Breaker jumpers, arresters and CVTs

700’ – 5” EHV Aluminum Tubular Bus Schedule 40 (for Bays and risers)

3 - 500kV CVT support structures (new octagonal design)

3 - 500kV CVT

4 - 500kV surge arrester support structures

4 - 230kV surge arrester support structures

4 - 500kV surge arrester for autotransformers

4 - 230kV surge arrester for autotransformers Long Lead Items

Qty Item Lead Time

3 500kV/230kV/13.8kV single phase auto-transformers, 160/212/267MVA

26-32 Months

1 500kV IPO breaker foundations, 3000A, 63kA 28-32 Wks

2 500kV, 3000A, GOAB vertical break, with 125VDC motor operator

14-16 Wks

22 500kV porcelain post insulators 24-26 Wks

3 500kV CVT support structures (new octagonal design) 20-22 Wks

3 500kV CVT 26-29 Wks

1,200’ Strain Bus Tri-Bundled 954 ACSR (45/7) 22-24 Wks

700’ 5” EHV Aluminum Tubular Bus Schedule 40 10-12 Wks

4 500kV surge arrester support structures 10-12 Wks

4 230kV surge arrester support structures 10-12 Wks

4 500kV surge arrester 14-16 Wks

4 230kV surge arrester 14-16 Wks

Relay:

The Hartburg relay drawing file contains over 250 Hartburg 500kV and 230kV drawings. All new drawings must begin the title description with the voltage class of the equipment associated with the drawing.

It is assumed that there is adequate space in the control house for the work required at Hartburg substation. Panel removal may be required to create adequate space.

Purchase, design and install one (1) line relay panel using SEL Mirrored Bits over digital circuits for primary relaying communication referencing Entergy standard PM1803, option C, latest revision. This panel incorporates a SEL 421 relay for primary 1 protection and an SEL model 311C for primary 2 protection. This panel will interface with a new L-195”b” SEL 421 primary relay at the NSS substation.

Establish protective relay telecommunications circuits between Hartburg and NSS for portion “b” of line 195. This study assumes the


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circuits will be a redundant system of digital microwave and backbone/T-line OPGW fiber via the Liberty/Pearl hub and direct fiber via the new 230kV line to NSS.

Purchase, design and install one (1) line relay panel using SEL Mirrored Bits over digital circuits for primary relaying communication referencing Entergy standard PM1803, option C, latest revision. This panel incorporates a SEL 421 relay for primary 1 protection and an SEL model 311C for primary 2 protection. This panel will interface with a new line SEL 421 primary relay at the NSS substation.

Establish protective relay telecommunications circuits between Hartburg and NSS for new line. This study assumes the circuits will be a redundant system of digital microwave and backbone/T-line OPGW fiber via the Liberty/Pearl hub and direct fiber via the new 230kV line to Hartburg.

In addition to the OPGW fiber installed in the shield position on new 230kV line from NSS to Hartburg, an approximately four mile ADSS underbuild circuit will be installed on the Echo to Front Street line from the 230kV right of way to the Orange to Sulfur backbone fiber. These fiber paths will provide redundancy for secure relay communications.

It is assumed that there are adequate spare AC breakers on the existing AC panels to provide AC to the new equipment or it can be supplied via another panel.

It is assumed that the existing GE Harris D20 RTU main processor will be adequate with the installation of (2) two additional D20S cards with standard terminals.

Purchase, design and install one (1) Autotransformer Panel. The panel uses an ERL-phase T-Pro 8700 transformer differential relay for primary differential protection in a large differential zone. The protected zone will wrap from the line node side CTs of the 500kV breaker bushings to the line side autotransformer 230kV CTs, including autotransformer neutral CT input. The panel uses a SEL 387-6 transformer differential relay for backup differential protection in a small differential zone. The protected zone wraps from the high side CTs of the autotransformer to the low side CTs of the autotransformer including neutral CT input. Provision for delta tertiary CT input to the T-Pro is also made for future use.

Purchase, design and install two (2) bus differential panels referencing Entergy standard PM0602, latest revision. This panel incorporates a SEL 487B relay for current differential protection. The high side bus differential panel protected zone will wrap from the high side 500kV CTs of the autotransformer to the line node side CTs of the 500kV circuit breakers. The low side bus differential panel will wrap from the low side 230kV CTs of the autotransformer to the line node side CTs of the 230kV circuit breakers. These bus differential panels will function as backup protection of the high and low side portions of the large zone autotransformer protection.


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This scope assumes that the tertiary will be included in the autotransformer but not bussed out. Two sets of CTs on each bushing must be provided on the tertiary for future use.

Modify the zone of protection of the existing autotransformer panel. The panel uses an SEL 387 differential relay for primary differential protection in a large differential zone. With installation of dual breakers on both the high side and low side of the existing autotransformer, the SEL 387 will not have adequate current inputs to wrap this zone. The protected zone will be modified to wrap the high side and low side CTs of the autotransformer, including autotransformer neutral CT input.

Purchase, design and install one (1) Autotransformer Panel. The panel uses an ERL-phase T-Pro 8700 transformer differential relay for primary differential protection in a large differential zone. The protected zone will wrap from the line node side CTs of the 500kV breaker bushings to the line side autotransformer 230kV CTs, including autotransformer neutral CT input. The SEL 387-6 transformer differential relay for backup differential protection in a small differential zone will be deleted from the panel. Provision for delta tertiary CT input to the T-Pro is also made.

Purchase, design and install two (2) bus differential panels referencing Entergy standard PM0602, latest revision. This panel incorporates a SEL 487B relay for current differential protection. The high side bus differential panel protected zone will wrap from the high side 500kV CTs of the autotransformer to the line node side CTs of the 500kV circuit breakers. The low side bus differential panel will wrap from the low side 230kV CTs of the autotransformer to the line node side CTs of the 230kV circuit breakers. These bus differential panels will function as backup protection of the high and low side portion of the large zone autotransformer protection.

Install seven (7) new 230kV CVT with Carrier accessories per Entergy standard PN0201, latest revision. All CVTs are to be purchased with carrier accessories for coordination and ease of construction purposes.

Purchase and install two (2) three phase potential junction box per Entergy Standard.

Purchase and install one (1) single phase potential junction box per Entergy Standard.

Install three (3) new 500kV CVTs per Entergy standard PN0201, latest revision.

Purchase and install one (1) three phase potential junction box per Entergy Standard.

Purchase, design, and install five (5) EHV Breaker Control Panels referencing Entergy standard PM0501 option B, latest revision. The panel uses a SEL 451 relay for breaker control and protection. These panels will be used for protection and control of the new 500kV and 230kV circuit breakers.


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Complete design of the AC and DC control schematics as well as the monitoring alarms for the new 500kV and 230kV circuit breakers will be required.

Long Lead Items:


5 Breaker control panel 12-14wks

2 Line relay panel 12-14wks

2 Autotransformer Diff Panel 12-14wks

4 Bus Diff Panel 12-14wks



Relay settings: Develop relay settings for transformer, line and breakers RTU Configuration: Develop RTU configuration and display of equipment and control at TOC


Install 2nd auto (T1) with 1 new 500kV breaker, bus CVT’s and 2 MOS making all connections necessary with only SW13552 and Breaker 13125 open. Once transformer high side MOS connections are installed, 500kV ring can be put back to normal until 2nd auto (T1) is ready for connection to new 230kV bus.

Install 3 new 230kV breakers, north bus CVT’s and replace all switches except existing L195 line switch while making all bus connections on north half of new 230kV ring bus to low side of New T1.

New T1 connections low side to new north bus of 230 yard may require reactor outages, if this is necessary the reactors will need to be out of service for approximately 2 days to install jumpers.

When T1 is ready for service and connected to 230kV north bus, it can be energized and commissioned with interruption of L195 Hartburg to inland orange while existing T2 is brought offline. During this interruption of loop power flow, relaying upgrades at Hartburg will be done to incorporate new 230kV bus schemes and line relaying. During this break in loop flow, the existing T2 connections can be reworked with breaker relocations and switch replacements with bus CVT installations along the south 230kV bus taking place.

Expected duration of this work is 21 days at Hartburg with Helbig carrying L195 load up to Inland Orange tap.

After T1 is commissioned and the new 230kV bus capable of carrying load of L195 circuit up to McLewis, the Helbig section of L195 up to McLewis will be taken out to facilitate the relay work necessary at Helbig for bus tripping scheme necessary for remote end(new Hartburg 230kV Bus). L195 may need to be out completely,


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if only briefly while the Helbig end is opened and load swap over to new Hartburg 230kV bus is performed.

Helbig relay work will take approximately 14 days to incorporate new remote end bus tripping scheme and panel installation.

The above process assumes the New 230kV substation will not be ready for connection to L195 when the new Hartburg bus equipment is ready for installation. Relay upgrades will follow at Hartburg and Helbig when the existing L195 and new line are cut into the new substation at L195 and L572 intersection.

Outage Planning: (To be submitted into AORS once further clarification is detailed)

Assuming above scenario:

New T1 node/500kV ring – 14 days while new T1 High side connections are made

L195 Hartburg to Inland Orange – 21 days while New 230 bus is made ready

L195 Helbig to McLewis – 14 days for relay upgrade


Live substation work and proximity of 500kV circuits to be addressed. Clearances, grounding and work zone flagging should be discussed and enforced. Tripping of L195 while loads carried from remote ends should be discussed in relay scope documentation to prevent inadvertent load drops (McLewis and Inland Orange taps)


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4.8 New 230 kV line to New Substation from Hartburg

The above drawing shows the location of the new 230kV sub along with the proposed cut-ins of L572, 195 and the new 230kV line. All proposed lines have been made turquoise and all proposed structures are represented by white circles. Line 572 is heading north from Sabine Sub and will transition into the east side of the new substation. It will continue out of the west side of new sub and continue towards Georgetown sub. L195 is coming from McLewis sub and will cut-into the new sub. It will leave the west side of the sub and follow its existing corridor. The new 230 kV line is coming from Hartburg sub following the same corridor as L195. It will transition into the new 230kV sub on the east side.

The Hartburg to NSS 230 kV line needs to have a capacity of 1150 MVA

Line Data MVA


1150 MVA


1190 MVA

Affected line length 15 mi


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Line route:

The new substation will be placed north of the intersection of L195 and L572. The new line will follow the same corridor as L195 from Hartburg and transition into the new substation.


The 15 mile line from Hartburg to NSS 230kV will require the installation of approximately 119 new concrete poles and 11 steel poles. Self-supporting steel dead-ends in drilled pier foundations and Direct-embedded concrete tangent structures will be used. The line will be in a delta configuration on the tangent structures and in a vertical configuration on the dead end structures.


The line will require the installation of approximately 432 insulator assemblies.

The will require the installation of approximately 936,700 lbs of bundled 1590 ACSR “Lawping” conductor.



ROW

The line will be adjacent to L195 and will require all new 100’ ROW with the structure placed on the centerline. 50’ will be on each side of the structure. The existing right of way extending from the new substation site to Hartburg is approximately 15 miles in length and varies in width from 220’ to 280’ and was acquired some years ago for multiple t-lines. No additional ROW is required for the new t-line since there is an available slot within this existing ROW corridor. Permits would have to be secured for railroad and highway/road. Although no additional ROW is required, we would still need to update the ownership along the ROW so as to give impacted landowners prior notice of our construction activities. The time allowed for ROW agent to coordinate updating ownership, notify impacted landowners, securing permits would be approximately 3 or 4 months from time the permit sketches are received from our Design Department.

Environmental Permits

A routing study is required to be performed and secure a CCN. Estimated time for completion is 18 months. If we have intervention in the CCN proceedings, which is very likely, the cost could escalate from $300,000 to $1,000,000 due to hearings and testimony filings and answering RFI’s.


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Wetlands assessment and USACE permitting can take up to a year to complete due to the backlog at the U.S. Army Corps of Engineers. The cost would be approximately $150,000. Mitigation for wetlands is another issue. Assuming the area we are proposing to build the line the worst case is that the PUCT would not allow us to build the line in the existing ROW and need to purchase new ROW. In this area we could assume 50% of the line could be considered wetlands. Mitigation credits could cost $25,000 per credit. Assuming 150 foot wide ROW times 15 miles would equal 272 acres. Assuming 50% is wetland (136 Acres) requiring mitigation at $25K per credit we could be looking at $3,400,000 for mitigation. Preparing the mitigation documents and purchasing the credits could take 6 months to complete.





936,700 lbs Conductor 2-1590” 22 weeks

88,000 lbs Cable, OPGW, 48-Fiber Alumacore 16 weeks


Construction methodology for new line construction:

Storm water mitigation controls will be installed in accordance with the SWPPP. The line work will be a bid job and contracted out. There is some vegetation removal to reclaim the ROW and this work will be bid and contracted out as well. There are some distribution crossings as well as FM road crossings. These locations will be guarded/covered-up and appropriate hot line holds or one-shots will be requested. Matting is required to traverse in any areas deemed as wetlands. Matting will also be required to cross any pipelines. The line will be staked and one call will be made in advance of construction. Any locations near pipelines or other underground utilities will be moved (with design’s approval) and re-marked or hydro probed. Line can be built end to end then energized when the station is ready for service. The assumed crossing of existing L195 will be underneath not requiring outages and the path will be north of L525 resulting in no crossing.

Outage Planning:

None required for new line if conductor at Hartburg is installed over south 230kV bus to DE #1 during work at Hartburg. Assume route is north of L525 circuit and west of L81 from preliminary layout.

If this circuit is in service and capable of feeding through NSS to carry McLewis and Inland Orange loads, the outage plan outlined for L195 can be reduced to opening breakers/switches at each station and upgrading the relaying at both Hartburg and Helbig.


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Safety consideration during construction:

Multiple parallel lines with multiple crossings, requiring guard structures and discussion of EPZ and proper grounding requirements. 4.9 Line Cut-in into New SS (Helbig to McLewis line)

Line Data MVA


685 MVA


780 MVA

Affected line length 5,000’

Line route

The new substation will be placed north of the intersection of L195 and L572. L195 will cut-in and out of the 230kV new substation. It will go in to the east side of the substation coming from McLewis sub and then transition out of the west of the substation going towards Helbig 230kV sub. Line length indicated above is for two lines (one from McLewis and the other from Helbig) and includes the work required on the main line as well as the right angle turn to bring the lines into the substation.


The cut-in to the NSS 230kV will require the installation of approximately 2 new concrete poles and 4 steel poles. Self-supporting steel dead-ends in drilled pier foundations and direct-embedded concrete tangent structures will be used. The line will be in a delta configuration on the tangent structures and in a vertical configuration on the dead end structures.


The line will require the installation of approximately 36 insulator assemblies. The line will require the installation of approximately 21,450 lbs of 1272 ACSR “Bittern” conductor.

7#7 will be used as the shield wire. Approximately 5,000’ will be installed.

ROW

New 100’ ROW will have to be acquired for the cut-in.

Relay settings at McLewis and Helbig:

Develop relay settings for transformer, line and breakers


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21,450 lbs Conductor, 1272 “Bittern” ACSS 22 weeks



When Substation is complete, take L195 McLewis to Helbig out to install cutover circuitry into station while performing necessary relay/settings work at Helbig. After circuit is re-established at Helbig feeding all the way to Inland Orange, L195 Hartburg to Inland Orange will be taken out to perform necessary relay/settings work at Hartburg. This circuit should be installed prior to L572 in order to avoid crossings.

Outage Planning:

L195 – McLewis to Helbig 5 days

L195 – Hartburg to Inland Orange 3 days

4.10 Line Cut-in New SS (Sabine to Georgetown lines)

Line Data MVA


685 MVA


780 MVA

Affected line length 4,500’

Line route

The new substation will be placed north of the intersection of L195 and L572. L572 will cut-in and out of the 230kV new substation. It will go in to the east side of the substation coming from Sabine sub and then transition out of the west of the substation going towards Georgetown 230kV sub. Line length indicated above is for two lines (one from McLewis and the other from Helbig) and includes the work required on the main line as well as the right angle turn to bring the lines into the substation.


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The cut-in to the NSS 230kV will require the installation of approximately 3 new concrete poles and 3 steel poles. Self-supporting steel dead-ends in drilled pier foundations and Direct-embedded concrete tangent structures will be used. The line will be in a delta configuration on the tangent structures and in a vertical configuration on the dead end structures.


The line will require the installation of approximately 33 insulator assemblies. The line will require the installation of approximately 19,300 lbs of 1272 ACSR “Bittern” conductor. 7#7 will be used as the shield wire. Approximately 4,500’ will be installed.

ROW

New 100’ ROW will be required for the cut-in.

Relay settings at Sabine and Georgetown:

Develop relay settings for revised length of line





19,300 lbs Conductor, 1272 “Bittern” ACSS 22 weeks



When Substation is complete, take L572 Sabine to Georgetown out to install cutover circuitry into station while performing necessary relay/settings work at both ends. This circuit should be installed after L195 in order to avoid crossings.

Outage Planning:

L572 – Sabine to Georgetown – 5 days

4.11 Sabine Substation – 230 kV:

Replace 8 breakers (13180, 13185, 13190, 13195, 13200, 13255, 13260, and 13265) with an interrupting rating of at least 47kA - 63kA IPO breakers.


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IPO breakers will not fit on existing GCB breaker foundations and these foundations will have to be replaced or modified.

Assumptions:

North and South buses are 6” Schedule 80 Al, do not require upgrading.

None of the old breakers have PCB’s.

Existing breakers have 2 ground jumpers and will be reused.

Existing ground grid does not have to be upgraded and is currently sized to handle the required 47kA fault currents.

Site Work

Site Work will include the following:

Install 200 tons of crushed rock (25 tons @ 8 locations) in areas disturbed by the breaker replacements.

Foundation Work

Foundation Work will include the following:

Remove/Modify 8 – 230kV GCB or OCB breaker foundations

Install 8 – 230kV, 3000 A, IPO Breaker foundations.

Install 6 – new 2” conduits per breaker in 30’ of trench/ breaker (Total of 1,450’ of conduit w/ 240’ of trench)

Electrical Work

Electrical Work will include the following:

Remove and dispose 8 – 230kV GCB or OCB breakers

Install 8 – 230kV, 3000 A, IPO Breaker foundations.

Install bundled 1590 ACSR (45/7) conductors including new terminals (200’ per breaker – 1,600’ total – 3100#) for jumpers from breakers to switches.

Connect existing ground jumpers to breakers.

Long Lead Items

Qty Item Lead Time

8 230kV, 3000 A, IPO Breaker, 63kA 18-22 weeks

48 Terminal, (2) 1590 ACSR (45/7) 12-14 weeks

Relay:

The Sabine relay drawing file contains hundreds of Sabine 230kV and 138kV drawings. All new drawings must begin the title description with the voltage class of the equipment associated with the drawing.

Reconfigure L-572 relaying for cut-in of the NSS substation. The existing panel uses SEL Mirrored Bits over digital circuits for primary relaying communication referencing Entergy standard PM1803, option B. This panel incorporates a SEL 421 relay for primary protection and an SEL model 311C for backup distance


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protection. This panel will be repurposed to interface with a new L-572”a” SEL 421 primary relay at the new NSS substation.

Establish protective relay telecommunications circuits between Sabine and NSS for portion “a” of line 572. This study assumes the circuits will be a combination of digital microwave via the Liberty/Pearl hub and backbone/T-line OPGW fiber.

Eight new IPO breakers will be installed at Sabine. Purchase, design, and install six (6) HV Breaker Control Panels referencing Entergy standard PM0501 option B, latest revision. The panel uses a SEL 451 relay for breaker control and protection. These panels will be used for protection and control of six of the new 230kV circuit breakers. The remaining two will be associated with L-572 to NSS. Existing breaker controls and relaying will be adequate.

Complete design of the AC and DC control schematics as well as the monitoring alarms for all affected/new 230kV circuit breakers will be required.

Long Delivery/Major Material Items:


6 Breaker control panel 12-14wks

Relay settings:

Develop relay settings for new breaker and for line to new SS.

RTU configuration:

Develop configuration for additional alarms required for the new breakers


Individual breakers to be undertaken as AORS schedule will allow. Generator 4 breakers will need coordination with generation outages. Other nodes to be scheduled and worked accordingly with individual outages per breaker

Outage Planning:

1 week per breaker undertaken.

G4 node to be coordinated with Sabine plant outage schedule –

Sabine RSS node – may also need plant coordination

Other breakers worked sequentially by bay to simplify relay changes possible to ratio or settings changes.


Live substation work and proximity of 230kV circuits to be addressed. Clearances, grounding and work zone flagging should be discussed and enforced. Tripping of lines or bus while loads carried from remote ends should be discussed in relay scope documentation to prevent inadvertent load drops.


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4.12 Helbig Substation – 230 kV:

Relay:

It is assumed that there is adequate space in the control house for the work required at Helbig substation. Panel removal may be required to create adequate space. Purchase, design and install one (1) line relay/breaker control panel using SEL Mirrored Bits over digital circuits for primary relaying communication referencing Entergy standard PM1803, option B, latest revision. This panel incorporates a SEL 421 relay for primary protection and an SEL model 311C for backup distance protection. This panel will interface with a new L-195”a” SEL 421 primary relay at the new NSS substation.

Establish protective relay telecommunications circuits between Helbig and NSS for portion “a” of line 195. This study assumes the circuits will be digital microwave via the Liberty/Pearl hub.

Long Delivery/Major Material Items:


1 Digital microwave equipment 20-22wks


Relay settings:

Develop relay settings for the new panel.


See Line cut in to NSS Section 4.9.


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4.13 Georgetown Substation – 230 kV:

Relay:

Reconfigure L-572 relaying for cut-in of the NSS substation. The existing retrofit panel uses SEL Mirrored Bits over digital circuits for primary relaying communication referencing Entergy standard PM1803, option B. This panel incorporates a SEL 421 relay for primary protection and an SEL model 311C for backup distance protection. This panel will be repurposed to interface with a new L-572”b” SEL 421 primary relay at the new NSS substation.

Establish protective relay telecommunications circuits between Georgetown and NSS for portion “b” of line 572. This study assumes the circuits will be digital microwave via the Liberty/Pearl hub.

No material is involved and the cost of work will be charged to line WO

Relay settings:

Develop relay settings for line to new SS


See Line cut in to NSS Section 4.10 Note: the cost for this task is included in the Sabine - Georgetown cut in described in Section 4.10.


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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.

Estimated Task Costs

2011 2012 2013 2014 Total

Grimes add transformer $87,699 $407,792 $18,541,375 $5,631,940 $24,668,806

Grimes to Mt Zion line $93,349 $920,525 $11,929,373 $1,433,608 $14,376,855

Hartburg $50,034 $466,089 $12,933,424 $15,512,937 $28,962,485

New SS $4,354 $318,263 $6,146,279 $4,090,937 $10,559,832

Helbig $1,843 $12,580 $390,800 $200,588 $605,811

Sabine $2,470 $50,691 $3,219,787 $1,653,920 $4,926,868

Toledo Bend $2,997 $3,990 $4,429 $30,794 $42,210

Toledo Bend - Leach $9,335 $673,374 $633,137 $875,508 $2,191,354

Newton - Leach $75,551 $6,741,323 $10,911,368 $15,500,280 $33,228,523

Line cut-in to New SS McLewis – Helbig line $2,470 $16,467 $42,322 $719,928 $781,187

Line cut-in to New SS Sabine – Georgetown line $2,470 $16,467 $58,541 $734,404 $811,883

Hartburg - New SS Line $25,331 $814,522 $6,971,619 $9,188,078 $16,999,550

Total: $357,903 $10,442,083 $71,782,454 $55,572,924 $138,155,365


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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 FFR Payment Section

Grimes add transformer $24,668,806 $24,668,806 4.4

Grimes to Mt Zion line $14,376,855 $14,376,855 4.5

Hartburg $28,962,485 $28,962,485 4.7

New SS $10,559,832 $10,559,832 4.6

Helbig $605,811 $605,811 4.12

Sabine $4,926,868 $4,926,868 4.11

Toledo Bend $42,210 $42,210 4.2

Toledo Bend - Leach $2,191,354 $2,191,354 4.1

Newton - Leach $33,228,523 $33,228,523 4.3

Line cut-in to New SS McLewis - Helbig line $781,187

$781,187

4.9

Line cut-in to New SS Sabine to Georgetown line $811,883

$811,883

4.10

Hartburg - New SS Line $16,999,550 $16,999,550 4.8

Total: $ 138,155,365 $ 42,210 $ 138,113,154

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 December 2014. Based on an assumed customer approval to proceed with the project by the end of September 2011, the following are approximate schedule dates:

Notes to Duration Schedules:

Pre-existing scheduled line outages may prevent the commencement of work. Scheduled outages cannot be confirmed until a firm construction schedule is submitted.

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.

Design and Construction resources are available when required.

Different resource is used for each design, so all designs start at same time.


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Transmission Line and Substation projects will begin subsequent to completion of Definition phase preparing PEP and having customer approval to proceed with the design/procurement and construction.

This schedule does not account for adverse weather conditions.

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

Scheduling assumption and completion dates for the project:

The completion date is driven by longest duration for delivery of transformers (32 months) 18 months for securing CCN permits for Hartburg to New SS line.

Submission to ICT by 06/11.

Approval to proceed with the project and creation of FP and WO – end of October 2011

Definition phase – completion of PEP/Estimates – end of March 2012

Approval from customer to proceed with the project by end of April 2012

Revised FP approved by end of May 2012

Commence Engineering, order material, ROW easement, environmental permitting, etc – end of June 2012

Start ordering process for transformers (Hartburg and Grimes) in May 2012 and order rest of substation and line material by September 2012

Material for Toledo – Leach – Newton lines to be delivered by March 2013 with the exception of transformers as their delivery would take 32 months arriving in November 2014.

Secure ROW and permits for Grimes to Mt Zion line by May 2013 and for New Substation (NSS), line cut-ins by November 2013 (reason – CCN permits)

Issue design for Toledo bend – Leach – Newton line and associated substation by November 2012.

Issue design packages for Grimes SS and line by May 2013.

Issue design for New SS (NSS), line cut-ins and Hartburg line by June 2013.

Rebuild Toledo Bend – Leach – Newton lines in 4 installments using 2 crews during 8 weeks (March - April 2013), 12 weeks (October – December 2013), 12 weeks (Feb – April 2014), 8 weeks (Oct – Nov 2014)

Construct Grimes Substation and Mt Zion to Grimes line starting June 2013 for completion by June 2014. Demolish existing Mt Zion to Grimes line and restore ROW by July 2014

Commence construction on Hartburg line, new SS and line cut-ins after receiving CCN approvals in October 2013 and complete it by November 2014. Install transformers at Grimes and Hartburg in December 2014 and complete the project.

Possibility of advancing in-service date to summer of 2014 – December 2014 in-service date is driven from delivery time of 32 weeks for transformer/IPO breakers. If we get permission from customer to order transformers, IPP breakers, commence property acquisition and start CCN process in September 2011 without waiting for the PEP/Estimate to be completed in February 2012 followed by FP approval and then ordering of transformer in May 2012, it would be possible to advance in-service date for transformers but the Toledo – Leach – Newton line upgrade, even with doubling crew would not be possible till November 2014. This also depends on SOC agreeing to the proposed outages in 4 installments.


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Additional assumptions made by construction.

Methodology in document based on satellite photos and existing one-lines -no field or site visits performed. Durations based on conventional durations per mile or typical device replacement undertaken.

All wood structures will be disposed of by either awarding to landowners or disposed of as regular creosote waste-no specially treated wood.

ROW is accessible by conventional means, no specialty equipment or extensive matting. ROW is maintained to the extent clearing is not necessary and no reseeding will be warranted.

Baseline or preferential contractors will be used eliminating the time required to competitively bid.


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8. RISK ASSESSMENT

Risk Comment Impact

ROW and Permits

Scope and estimate for new ROW is based on limited knowledge of individuals using the aerial views, etc on the internet and could vary considerably

****

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.

**

Uncertainty of ability to secure substation site and line cut-in Row for new SS

The selected site may not be available by the time easement or purchase of substation site is required. A new site may have to be picked impacting on the cost of SS site, line cut-in ROW and increased length of Hartburg line. Cost impact can not be determined at this time

***

CCN and other permitting could take longer than assumed in developing schedule Need revision to schedule

*

Transformer delivery could be delayed due to failure in testing or problems in transportation

Impact would be on completion date – could be delayed by several months to a year.

**

Cost of transformer and IPP breakers Prices could be higher at the time of placing the order

**

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


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9. CONFIRMED RESERVATIONS

OASIS PSE MW Begin End

250778 (undesignation) Entergy Services, Inc. (EMO) 1 7/2/1998 7/1/2011

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










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




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




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




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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


1472304 (renewal) South Miss Electric Power Assoc. 75 6/1/2009 6/1/2011

1472315 South Miss Electric Power Assoc. 100 6/1/2010 6/1/2011



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


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





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







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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




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


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

73741122 (renewal) Entergy Services, Inc. (EMO) 135 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





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


















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

74835023 AECI / APM 103 1/1/2012 1/1/2017 74881866 (renewal) NRG Power Marketing 8 3/1/2011 3/1/2021






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10. PRE-888 TRANSACTIONS









































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11. STUDY QUEUE




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





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

A Table of Acronyms

AC Alternating Current

ACAR Aluminum Conductor Alloy Reinforced

ACSR Aluminum Conductor Steel Reinforced

ACSS Aluminum Conductor Steel Supported

ADEQ Arkansas Department of Environmental Quality

AFUDC Allowance for Funds Used During Construction

Ah Amp Hours

AM Asset Management

AORS Automatic Outage Request System

ASPEN Advanced Systems for Power Engineering

ATC Available Transfer Capability

CCN Certificate of Convenience and Necessity

CCVT Coupling Capacitor Voltage Transformer

CT Current Transformer

CU Cubic

CVT Current Voltage Transformer

CYDS Cubic Yards

CZM Coastal Zone Management

FDC Direct Current

DE Dead-End

DFR Digital Fault Recorder

DTT1/DTT2 Direct Transfer Trip

EES Entergy Control Area

EHV Extra-High Voltage

EPZ Equal Potential Zone

ERIS Energy Resource Interconnection Service

FM Farm to Market Road

FP Funded Project

FTLO For The Loss Of

GCB Gas Circuit Breaker

GE General Electric

GOAB Gang-Operated Air Brake

GSU Gulf States Utilities

HPS High Pressure Sodium

ICT Independent Coordinator of Transmission

IPO Independent Pole Operated

ISD In-Service Date

KCMIL Equivalent cross-sectional in thousands in circular mills

KD A type of electro-mechanical relay

kV Kilo-Volt

KVA Kilo-Volt Amps

LA Lightening Arrestor

LBS Pounds

MCM (M) Thousand Circular Mils

MITC Methylisothiocyanate

MOS Motor Operated Switch

MUST Managing and Utilizing System Transmission

MVA Mega-Volt Amps

MW Mega-Watt

NEPA National Environmental Policy Act


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NPDES National Pollution Discharge Elimination System

NOI Notice of Intent

NRIS Network Resource Interconnection Service

NSS New Substation

OASIS Online Access and Same-time Information System

OATT Open Access Transmission Tariff

OPGW Optical Power Ground Wire

PCN Pre-Construction Notification

PEP Project Execution Plan

POD Point of Delivery

POR Point of Receipt

POTS Post Office Telephone Service

POTT Permissive Overreaching Transfer Trip

PRC Protection and Control

PSS/E Power System Simulation program

PT Potential Transformer

PTI Power Technologies Incorporated

PUCT Public Utilities Commission of Texas

PVC Polyvinyl Chloride

PVD Programmable Voltage Detector

RCP Reinforced Concrete Pipe

RFI Request For Information

ROW Right of Way

RTU Remote Terminal Unit

SEL Schweitzer Engineering Lab

SES Steam Electric Station

SHPO State Historic Preservation Office

SOC System Operations Center

SHV Super High Voltage

SS Substation

SSVT Station Service Voltage Transformer

SW Switch Station

SWPPP Storm Water Pollution Prevention Plan

TAOR Transmission Automatic Outage Request system

TOC Transmission Operations Center

USACE United States Army Corps of Engineers

VDC Volts Direct Current

WO Work Order

WOTAB West Of The Atchafalaya Basin


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B Scope Summary Diagram / Area Maps

Toledo Bend Area

Toledo Bend – Leach 230 kV Line Upgrade Newton Bulk – Leach 138 kV Line Upgrade

Page 67

Grimes – Mt Zion Area

Grimes - Mt Zion 138 kV Line Upgrade Grimes Substation Upgrade

Page 68

New Switch Station Area

New Switch Station (NSS) 5 Terminal Ring Exiting Line Cut-in to NSS Hartburg – NSS 138 kV Line – New 230 kV Line Sabine Substation Upgrade

Page 69

C One line & Substation Layout Drawing

One Lines GXXXXSO5 NSS 230 kV (New Switch Station) Page 70

G1207SO5 Georgetown 230 kV Substation Page 71

G1136SO5 Helbig Bulk 230 kV Substation Page 72

G1167SO5 Hartburg 500 kV Substation Sh-1 Page 73

G1167SO5 Hartburg 500 kV Substation Sh-2 Page 74

G1710SO5 McLewis 230/34.5 kV Substation Page 75

G1259SO5 Inland Orange 230 kV Substation Page 76

G2143SO6 Sabine 230/138 kV Substation Sh-2 Page 77

G2143SO7 Sabine 230/138 kV Substation Sh-3 Page 78

Substation Layouts

G1167EA2 Hartburg 500 kV Substation Page 79

G1167EA4 Hartburg 500 kV Substation (Addition) Page 80

D – Duration Schedules

Duration Schedule Summary Page 81

Upgrade Toledo Bend – Leach 138kV Line to 170 MVA or Greater

Upgrade Newton Bulk – Leach 138kV Line to 168 MVA or Greater

Toledo Bend AreaT-Line Upgrades

Upgrade Grimes – Mt Zion 138 kVLine to 250 MVA or Greater

Grimes – Mt Zion AreaLine Upgrades & Substation

Expansion

Install 3rd 345/138 kV 525 MVAAutotransformer atGrimes Substration

New Switch Station(NSS) 5 Terminal

230 kV

New 230 kV LineNSS-Hartburg

1150 MVA or Greater(Same corridor as L195)

Upgrade 8 230 kVBreakers to 63kA IPO

New 500/230 kV 800MVA Autotransformer

New Switch Station Area230 kV Lines and Substation

Locations

H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\NSS\GXXXXEA1 - NSS.dwg, 4/25/2011 2:02:00 PM, lbernad

H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\one-lines\G1207SO5 - Georgetown.DWG, 4/25/2011 1:36:58 PM, lbernad

H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\one-lines\G1136SO5 - Helbig.DWG, 5/25/2011 12:50:46 PM, lbernad

H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\one-lines\G1167SO5 - Hartburg1.DWG, 4/25/2011 1:52:49 PM, lbernad

H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\one-lines\G1167SO6 - Hartburg2.DWG, 4/20/2011 11:27:23 AM, lbernad

H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\one-lines\G1710SO5 - McLewis.DWG, 5/25/2011 12:53:56 PM, lbernad

H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\one-lines\G1259SO5 - Inland Orange.DWG, 5/25/2011 12:54:29 PM, lbernad

H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\one-lines\G2143SO6 - Sabine2.DWG, 5/25/2011 12:53:24 PM, lbernad

"FOR SAFETY/G

ROUN

DIN

G PURPOSES TH

E AVAILABLE FAULT CURRENT IS ABO

VE 40kA."

H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\one-lines\G2143SO7 - Sabine3.DWG, 5/25/2011 12:52:38 PM, lbernad

"FOR SAFETY/G

ROUN

DIN

G PURPOSES TH

E AVAILABLE FAULT CURRENT IS ABO

VE 40kA."

H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\Hartburg 230kv\G1167EA2 - Hartburg1.DWG, 5/3/2011 9:00:12 AM, lbernad

H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\Hartburg 230kv\G1167EA4 - Hartburg2.DWG, 5/3/2011 8:58:23 AM, lbernad

OASIS 74900000Facility Study

Project Duration Summary

2011 end ofFeb Mar April May June July Aug Sept Oct Nov Dec

0 0 4 4 4 4

Customer +FPApproval 4 4

2012Jan Feb Mar April May June July Aug Sept Oct Nov Dec

Complete PEP customer approval

Revised FPapproval + ordertransformers/IPObreakers

commencedesign/ROW/enviromental

Order allmaterial

Issue design forToledo - Leach -Newton


Receive material including IPO bkrs butXFMRs + commence const for Toledo -Leach line

ConstructToledo - Leachline

Issue design forconstruction -Grimes/Mt Zionline + Sabine

Issue design forconstruction -NSS/line cut-ins/Hartburg line +relay design for lineend Substations

CommenceConstructionat Sabine

ConstructNewton -Leach line

ConstructNewton - Leachline +completeROW/CCN +environmental

ConstructNewton -Leach line +Grimes, MtZion, NSS, &Hartburg line


ConstructNewton -Leachline Construct Newton - Leach line

ConstructNewton - Leachline

ConstructNewton -Leach line

ConstructNewton - Leachline + Receivetransformers

CompleteConstincludingGrimes,McLewis,Helbig,GeorgeTown andSabine

ictt-2010-150 transmission service facilities study …the equipment at toledo bend needs to be...

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