TRANSMISSION LINE & SUBSTATION PROJECTS · PDF fileTRANSMISSION LINE & SUBSTATION PROJECTS...

TRANSMISSION LINE & SUBSTATION PROJECTS

COMPANY:ENTERGY SERVICES, INC.

CUSTOMER: SRMPA

FACILITIES STUDY

EJO NO. F4PPMS0268

ICTT-2012-009

TRANSMISSION SERVICE FACILITIES STUDY OASIS 76523753

Revision: 0

Rev Issue Date

Description of Revision Prepared

By Approved

By

A 05/21/12 Shell for team input IK/KC RT

B 05/30/12 Construction input IK/KC RT

C 06/11/12 Incorporated OASIS 76523750 comments

IK/KC RT

D 06/13/12 TPD Approval RB BW

0 06/28/12 ICT Determines Upgrade Classification Sherri Maxey

Benjamin Roubique

OASIS 76523753 SRMPA Facilities Study

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TABLE OF CONTENTS

1. PROJECT SUMMARY ....................................................................... 3

1.1 Background and Project Need ............................................................................... 3

1.2 Scope Summary ..................................................................................................... 3 1.2.1 Mossville 138 kV: Cut-in line 616 (Nelson – Carlyss 138 kV) .................... 3

1.2.2 Upgrade the PPG – Rose Bluff 230 kV transmission line .......................... 3

1.2.3 Affected System Study .............................................................................. 4

1.3 Cost Summary ....................................................................................................... 4

1.4 Schedule Summary ............................................................................................... 4

2. SAFETY REQUIREMENTS & GENERAL ASSUMPTIONS ............... 4

3. GENERAL ASSUMPTIONS ............................................................... 5

4. SCOPE OF WORK ............................................................................. 5

4.1 Mossville 138 kV: Cut-in line 616 (Nelson – Carlyss 138 kV) ............................... 5 4.2 Mossville Substation .............................................................................................. 8

4.3 Carlyss Substation .............................................................................................. 12 4.4 Bayou D’Inde Substation ..................................................................................... 13 4.5 Orange Substation .............................................................................................. 15

4.6 Nelson Substation ............................................................................................... 16 4.7 Upgrade the PPG – Rose Bluff 230 kV transmission line .................................... 18

5. COST ............................................................................................... 21

6. UPGRADE CLASSIFICATION ......................................................... 21

7. SCHEDULE ...................................................................................... 22

8. RISK ASSESSMENT ....................................................................... 23

9. CONFIRMED RESERVATIONS ....................................................... 24

10. PRE-888 TRANSACTIONS .............................................................. 29

11. STUDY QUEUE ................................................................................ 31

12. ATTACHMENTS .............................................................................. 32

12.1 Table of Acronyms .............................................................................................. 32 12.2 Drawings ............................................................................................................. 32


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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 SRMPA request for 30 MW of yearly network transmission service. The time period for this transfer is from 6/1/2012 until 6/1/2016. The direction of the transaction is EES to EES. The study was performed on the latest available June 2012 – December 2013 monthly models, 2013-2015 winter and 2014-2016 summer peak seasonal models using PSS/E and MUST software by Power Technologies Incorporated (PTI). The Facilities Study identifies any transmission constraints resulting from the requested power transfer. The Facilities Study also includes cost estimates to correct any transmission constraints.

1.2 Scope Summary

ATC is not available for 6/1/2012-6/1/2014. The following constraints are identified from 6/1/2012-6/1/2014.

Rose Bluff – PPG 230 kV FTLO Carlyss – Nelson 230 kV

Kountze – Lumberton 138 kV FTLO Cypress – Bevil – Amelia 230 kV

Helbig – McLewis 230 kV FTLO Cypress – Hartburg 230 kV

Cypress 500/138 kV autotransformer FTLO Cypress 500/230 kV autotransformer

For ATC beyond 6/1/2014, the following upgrades are required prior to the start of transmission service.

1.2.1 Mossville 138 kV: Cut-in line 616 (Nelson – Carlyss 138 kV)

The Mossville – Nelson 138 kV transmission line overloads for the loss of the Citcon West – Arizona 138 kV transmission line. The cut-in of line 616 (Nelson – Carlyss 138 kV) into the Mossville 138 kV substation will alleviate this constraint. This project is proposed in the 2012-2016 Entergy Construction Plan with an expected ISD of Summer 2013.

1.2.2 Upgrade the PPG – Rose Bluff 230 kV transmission line The PPG – Rose Bluff 230 kV transmission line overloads for the loss of the Carlyss – Nelson 230 kV transmission line. It is required that the PPG – Rose Bluff 230 kV transmission line be upgraded from a capacity of 470 MVA to at least 482 MVA, 1210 A.


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The PPG – Rose Bluff 230 kV transmission line has been identified as a required upgrade in a prior Facilities Study (OASIS request 76523750). If the prior transmission service request (OASIS request 76523750) and proposed upgrade is withdrawn, this customer would be responsible for this upgrade. The proposed upgrade is 519 MVA. The amount of capacity created by this upgrade is 49 MW, and the customer’s use of the capacity created is 2 MW.

1.2.3 Affected System Study

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

1.3 Cost Summary

The estimated total project cost in 2012 dollars is $11,360,932. This includes AFUDC and does not include Tax Gross Up, which may apply if and where applicable (Tax Gross Up rate at this time is 27.4%). The estimate includes AFUDC and it will be waived if customer makes prepayment. The ICT has assigned $7,718,253 as Base Plan upgrades and $3,642,679 as Supplemental Upgrades based on Attachment T of Entergy’s Open Access Transmission Tariff (OATT).

1.4 Schedule Summary The requested date for the start of network transfer is June 1, 2012. This date will not be met and based on Entergy project schedules, the upgrades will be completed by November 30, 2014.

2. SAFETY REQUIREMENTS & GENERAL ASSUMPTIONS

Safety Safety is a priority with Entergy. Safety will be designed into substations and lines. The designs will be done with the utmost safety for personnel in mind for construction, operation, and maintenance of the equipment. All employees working directly or indirectly for Entergy shall adhere to all rules and regulations outlined within the Entergy Safety manual. Entergy requires safety to be the highest priority for all projects. All Entergy and Contract employees must follow all applicable safe work procedures.


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3. GENERAL ASSUMPTIONS

Sufficient time will be allowed in approving the project enabling Entergy to prepare a PEP and be able to complete the project as per outlined in the schedule described provided below.

Assumptions have been made in developing estimates without performing site visits, surveys, and soil borings. During the PEP, these tasks will be completed and could have an impact on estimates and schedule.

All costs above represent good faith estimates and are based on existing data and could change considerably after development of a detailed project execution plan. Price escalation has been included in the estimate.

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

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 over-current 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 Mossville 138 kV: Cut-in line 616 (Nelson – Carlyss 138 kV) The Mossville – Nelson 138 kV transmission line overloads for the loss of the Carlyss – Citcon West 138 kV or Citcon West – Arizona 138 kV transmission line. The cut-in of line 616 (Nelson – Carlyss 138 kV) into the Mossville 138 kV substation will alleviate this constraint. Line relay panel replacement is required at Nelson and Carlyss substations.

Existing line capacity = 1091 Amps

Line cut-in capacity = 1303 Amps


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Line Route The new cut-in line 138kV Line 616 will run in just south of the substation. There will be rerouting of the existing 138 kV line 601 south of the substation and north of the substation for 138kV lines 295 and 274 to better suit the new cut-in Line 616. The new cut-in line will run approximately 0.35 mile into Mossville substation. ROW Entergy owns the property that the line and the substation are located on, so it is assumed that the new cut-in line will utilize the existing ROW. For a typical 138kV double circuit line, we require a 120’ ROW width. Environmental Permitting Based on observations of available aerial photography, no highway or railroad crossing permits are included in this estimate. Structures and Foundations The new line cut-in will require one (1) new tangent and six (6) new dead-end structures. As a result of rerouting existing lines into the substation, it is also estimated that an additional seven (7) dead-end structures will be required to reroute existing L-601, L-295, and L-274 into the substation. Dead-ends are assumed to be in drilled pier foundations and tangents are assumed to be direct embedded approximately 15’. This will be analyzed during the design phase of this project after geotechnical data is obtained.

Conductor and Insulators 1272 ACSR “Bittern” conductor, which can provide up to 1303 Amps at 212ºF, has been selected to match the ampacity of the existing 1033 AA Conductor installed on L-616. Based on the assumed line route described above, it is estimated that this new line cut-in and reroute of the existing line will require approximately 15,574 lbs. of new conductor. 161 kV polymer type insulators will be used on this project. It is estimated that the cut-in will require 87 dead-ends, and three (3) braced posts. Bolted type dead-end clamps will be used to match the 1272 ACSR conductor. Shield Wire Based on Entergy Standard practices, 48 fibers, 0.528 Alumacore OPGW (DNO-8161), will be used as the shield wire for this project. Approximately 3,630’ of fiber optic cable and four (4) splice boxes will be required. 7#7 Alumoweld will be used as a second shield wire where required.


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Long Delivery Items

Quantity Unit Description Delivery time

14 Each Steel Poles 20 weeks

12 Each Anchor Bolt Cage Foundations 20 weeks

93 Each Polymer Insulator Assemblies 12 weeks

15,574 Pounds 1272 ACSR “Bittern” Conductor 12 weeks

Construction Methodology

Construction is assuming normal construction methods because the substation is existing and Entergy-owned. It does not appear that wetlands will be an issue. Poles can be delivered to site and stored on location until time of construction to start. Any multiple piece poles will be jacked together on the ground instead of in the air. Foundation work will occur first to drill holes and set the foundations and backfill them with concrete. The foundations will be allowed to set and cure for seven (7) days minimum before any load will be added on top of the foundations. Concrete strength tests will also be conducted during the pour. As many Greenfield poles that can be set will be done so first to minimize outage durations. The reroute of lines 295 and 274 (on the north side of the substation) will require an outage on both lines at the same time. This work will also have to coordinate with the relay work for the line panels being performed inside the control house. Because of the congestion in the existing right of way, other line outages might be required depending on final locations of poles. Hot line holds will be required on neighboring lines, both transmission and distribution. L-601 will be rerouted on the south side of the substation and will no longer land on Bay A, but on Bay D instead. Minimal clearing of trees and brush will be required to move line 601 further south west. This will also have to coordinate with the installation of the new line panel being installed and associated relay work. The foundations will be set first and the concrete will be given a minimum seven (7) day curing time before setting the steel poles on top. Finally L-616 Carlyss to Nelson, which currently runs past Mossville station on the east side, will be cut and brought into the station. The line will be separated on the south end of the station with L-616 Mossville to Carlyss, terminating into Bay C, and the new line Mossville to Nelson, terminating on Bay A.


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Outage Planning Multiple outages will be needed to complete the scope of this project. TOC will be asked to perform a study to see the possibility of obtaining outages during the timeframe needed. It is known that taking out both bus 1 and 2 will be hard to obtain, as well as taking out two (2) lines at the same time. Because of geographical line constraints, several 69kv lines, as well as some distribution feeders, will require a hot line hold through TOC. Upon final determination of pole locations, additional line outages may be required to maintain proper working clearance. The outage request to have both lines 295 and 274 out at the same time will leave one (1) remaining line in service in the station to carry the entire load. This outage request is a large risk assumption. L-601 will require a two (2) week outage to move the line over to the new bay. An outage will be required on L-616 for to make the cut in for approximately two (2) weeks. Another three (3) day outage on L-616 to set the foundations under the line will be required before the cut in outage. The line outages will coordinate with the steel and electrical and relay outages for the same bay work. Safety consideration and risks during construction Follow all Entergy and OSHA rules including EPZ and grounding requirements, as well as clearance rules. An Entergy Operations Coordinator will be on site for a majority of the project.

4.2 Mossville Substation

General The station will be modified to accept the L-616 cut-in between Nelson and Carlyss. The cut-in line will enter the yard from the Westside and terminate into substation structure. Existing lines will need to be relocated at different position to prevent line crossing and minimize breakers failure. For reference, see the one-line and electrical arrangement. Site

Backfill and re-dressing of excavated soil and limestone from conduit, grounding and foundation installations.

Minor grading shall be required to ensure positive drainage away from foundations.

Foundations The foundation work shall be supplied, installed and built in accordance with Entergy specification and design drawings. Foundation installation recommendation specified in the Geotechnical Soils Report shall also form part of the installation requirement.


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The foundation scope of work includes design and constructs the following:

Six (6) foundations will be installed for the new 230kV adder bay.

Four (4) foundations will be installed for the new 138kV gas circuit breaker (dead tank).

Two (2) foundations will be installed for the new 138kV gas circuit breaker (live tank). Each breaker foundation has two (2) footers.

Nine (9) foundations will be installed for the new 138kV lightning arrester supports.

Four (4) foundations will be installed for the new 138kV CCVT supports.

Six (6) 2” PVC conduits will be installed from each of the circuit breakers to the existing cable trough. Two (2) 2” PVC conduits will be installed from each of the new CCVT junction box to the new cable trough. One (1) 2” PVC conduit will be installed from the CCVT junction box to each of the appropriate CCVT. Approximately 3,000’ of new conduits will be installed from the cable trough to the new equipment.

Install approximately 1,000’ of substation ground wire including pigtails to new equipment and structures. All new ground grid will be installed with 4/0 copper conductor. All new construction including 19 #9 copperweld “pigtails” will be tied to the new ground grid as per Entergy grounding standards.

Electrical

All equipment and structures shall be installed in accordance with Entergy specification and design drawings. Four (4) new adder bays will be installed to facilitate the new bus work and equipment. The new bus work will be connected to the existing bus work and will extend westward and southward. Three (3) of the existing lines will be relocated and terminated at different node to accommodate the new line cut-in. In addition, a 138kV gang operated live tank breaker will be installed on the high side of the transformer.

The electrical scope of work includes design and constructs the following:

Four (4) 230kV adder bays with trusses to match existing construction.

Four (4) 138kV, 3000A, 40kA dead tank gas circuit breakers.

Two (2) 138kV, 3000A, 40kA live tank gas circuit breakers.

Eight (8) 138kV 2000A vertical break disconnect switches will be installed and mounted vertically on the new 138kV (lower truss) adder bay. The switches designated as line switches will be equipped with a ground switch attachment.


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Two (2) existing disconnect switches (17973 and 17972) will be replaced with two (2) new 138kV 2000A vertical break disconnect switches. The switches will be relocated to the top section and mounted vertically on existing trusses. This will require the bottom truss to be moved up.

Six (6) 138kV CCVTs. Three (3) of the CCVTs will be for line relaying and mounted underneath the T-line. The other three (3) will be for bus relaying and mounted underneath the bus work between the new transfer breakers. The CCVT will be mounted on standard low bus equipment pedestal. A CCVT junction box will be mounted on each pedestal.

Six (6) existing PTs will be replaced with new CCVTs. The new CCVTs will be mounted on existing equipment structures. One set connected to T2 bus will be relocated and installed onto existing abandoned foundations. A new CCVT junction box will be mounted on one of the structure for each set of CCVT.

Fifteen (15) lightning arresters will be installed and mounted on standard low bus equipment pedestal. Six (6) will be installed for new L-616 cut-in. The other nine (9) will be installed for existing lines and mounted on existing abandoned foundations, except of three.

All new strain bus/jumpers will be 1252MCM ACSR (rated at 1303A).

Bus tie breaker #17965, disconnect switches #17964 & 17966, and L-295 line trap including structure will be removed for the new construction. Breaker foundation will be abandon in place.

Relaying The relay scope of work includes design and construction of the following:

Five (5) line/breaker control panels for line relaying and control of breakers associated with L-601 to Bayou D’Inde, L-616 to Carlyss, L-XXX to Nelson, L-295 to Orange, & L-274 to Nelson. Essentially all existing line terminals must be moved for adequate configuration of the substation. Due to outage constraints and construction sequence, new line relaying is required.

Purchase and install twelve (12) CCVTs for line and bus potential per Entergy Standard PN0201, latest revision. All CCVTs to be purchased with carrier accessories for coordination and ease of construction purposes.

Design, purchase and install four (4) High Voltage Breaker Control panels using the SEL 451 relay for all breaker protection and control functions per Entergy Standard PM0501, latest revision. These panels will control the bus tie breakers and the high side autotransformer associated breakers. The high side autotransformer breakers are proposed live tank breakers due to space constraints. Modification to the standard panels must be performed if flashover protection is required on the live tank breakers.


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Design, purchase, and install three (3) Bus Differential panels referencing Entergy Standard #PM0602. Each Bus Differential panel will be installed on one of the three buses in the station.

Relay Settings and configuration

Develop relay settings for five (5) line/breaker control panels utilizing Entergy standard relays and referencing Entergy standard PM1803.

Develop relay settings for four (4) High Voltage Breaker Control panels per Entergy Standard PM0501, latest revision.

Develop relay settings for three (3) Bus Differential panels referencing Entergy Standard #PM0602.

Edit RTU configurations to provide new inputs from the bus differential, line and breaker control panels.

Long Delivery Items


6 Each 138kV 3000A 40kA Gas Circuit Breaker 20-22 weeks

10 Each 138kV 2000A Vertical Break Disconnect Switch

14-16 weeks

1 Lot Substation Steels 10-12 weeks

126 Each 138kV Post Insulator 10-12 weeks

15 Each 138kV Lightning Arrester 14-16 weeks

4 Each HV Breaker Control Panel 14 Weeks

5 Each HV Line/breaker Control Panel 14 Weeks

3 Each Bus Differential Panel 14 Weeks

1 Each Stand Alone DC Panel 12 Weeks

12 Each 138kV CCVTs 28 Weeks

1 Set Batteries 24 Weeks

Construction Methodology and Outage Requirements

Construction will coordinate task work as to utilize outages so that they are short in duration and bundle work for fewer outage requests. Three (3) of the new bays, D, E and F, can be built “green field” without needing an outage. Half of bay C can be constructed Greenfield, but the East side of bay C will require an outage to set the foundations and to erect the steel. These new bays will take approximately three (3) months to complete. The jumpers to connect new bay F and the new strung bus on bay H can be installed utilizing an outage on Bus 2. An outage will be needed to connect the jumpers to bay C. Relay work inside the control house will be simultaneous with the steel construction. The line panels for L-274 and L-295 will be placed in an open location inside the control house ahead of the outage. An outage will be needed on both line 295 and 274 at the same time for four (4) weeks in order to wire in line relay panels,


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commission panels, and T-Line construction to swap around the two (2) transmission lines coming into the bays on the north side of the station. The outage request to have both lines 295 and 274 out at the same time will leave only one (1) remaining line in-service in the station to carry the entire load. This outage request is a large risk assumption. A bus tie relay panel and bus tie breaker will need to be ready to go when we move L-601 on the south side of the station. An outage will be needed to move line 601 from its current landing location to land on the new Bay D. The line panel work will also need to be coordinated during this time. The control house has room for four (4) new panels to be installed Greenfield. All remaining panels will require the retirement of old panels to make space for the new panels. This process will cause the line construction to be dependent on the relay work schedule. The steel truss on the east side of Bays A and B will need to be raised and switches installed to provide adequate clearance for the new breakers going in ahead of the autotransformers. These will be worked one transformer side at a time and will require an outage on each bus (not at the same time; one after the other). The new breakers will also be installed during the individual bus outages and the relay work for the panels will coincide with these outages, as well. Line 616 will be cut in the ROW adjacent to the substation, and made into two (2) lines. The two-line panels and the remaining bus tie breakers will need to be commissioned at this time. The new lines coming into the station will land on the south side into Bays C and A. The existing bus tie breaker 17965 will be removed from service. Entire construction time will take approximately five (5) months. New relay settings will be implemented and RTU configuration changes made.

4.3 Carlyss Substation

General Replace line relay panels to match with new line panels at Mossville substation. Site There is no site work. Foundations

Six (6) 2” PVC conduits will be installed from the control house to existing circuit breaker 18845. Approximately 1,000’ of new conduits will be installed between the existing breaker and control house.


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Electrical

There is no electrical work. Relaying

One (1) line/breaker control panel for line relaying and control of breaker associated with L-616 Mossville.

Relay Settings and configuration

Develop relay settings for one (1) line/breaker control panels utilizing Entergy standard relays and referencing Entergy standard PM1803.

Review change in fault current levels and revise settings for all terminals leaving Carlyss, if necessary.

Edit RTU configurations to accommodate input from new line panel.

Long Delivery Items




Conduit will be installed from the control house out to breaker 18845, and control cable will be pulled from the breaker into the control house. This will be approximately two (2) weeks of pre-outage work. A new line/breaker control panel will be mounted inside the Carlyss substation control house, and the existing line breaker 18845 will be wired into the new panel. A two (2) week outage on L-616 will be required for the line panel swap and commissioning. This will have to coordinate with the line cut-in at Mossville substation to match relays on both ends and for end-to-end checking. New relay settings will be implemented and RTU configuration changes made.

4.4 Bayou D’Inde Substation

General Replace line relay panels to match with new line panels at Mossville substation. Site There is no site work.


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Foundations

Six (6) 2” PVC conduits will be installed from the control house to existing circuit breaker 18625. Approximately 600’ of new conduits will be installed between the existing breaker and control house.

Electrical There is no electrical work. Relaying One (1) line/breaker control panel for line relaying and control of breaker associated with L-601 to Mossville. Relay Settings and Configuration


Review change in fault current levels and revise settings for all terminals leaving Bayou D’Inde, if necessary.


Long Delivery Items




Conduit will be installed from the control house out to breaker 18625 and control cable will be pulled from the breaker into the control house. This will be approximately two (2) weeks of pre-outage work. A new line/breaker control panel will be mounted inside the Bayou D’Inde substation control house, and the existing line breaker 18625 will be wired into the new panel. A two (2) week outage on L-601 will be required for the line panel swap and commissioning. This will have to coordinate with the line reroute at Mossville substation to match relays on both ends and for end-to-end checking. New relay settings will be implemented and RTU configuration changes made.


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4.5 Orange Substation

General Replace line relay panels to match with new line panel at Mossville substation. Site There is no site work. Foundations

Six (6) 2” PVC conduits will be installed from the control house to existing circuit breaker 3120. Approximately 1,250’ of new conduits will be installed between the existing breaker and control house.

Electrical

One (1) line trap including mounting structure will be removed from L-295.

New jumper will be 954MCM ACSR (rated at 1089A).

Relaying

One (1) line/breaker control panel for line relaying and control of breaker associated with L-295 to Mossville.

Relay Settings and Configuration


Review change in fault current levels and revise settings for all terminals leaving Orange if necessary.


Long Delivery Items




Conduit will be installed from the control house out to breaker 3120, and control cable will be pulled from the breaker into the control house. This will be approximately two (2) weeks of pre-outage work. A new line/breaker control panel will be mounted inside the Orange substation control house, and the existing line breaker 3120 will be wired into the new panel. A two (2) week


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outage on L-295 will be required for the line panel swap and commissioning. This will have to coordinate with the line cut-in at Mossville substation to match relays on both ends and for end-to-end checking. The removal of an existing line trap on L-295 and the installation of a new 954 mcm ASCR jumper in its place will also be completed during the same two-week outage. New relay settings will be implemented and RTU configuration changes made.

4.6 Nelson Substation

General

Install single phase CCVT. Replace line relay panel to match with new line panel at Mossville.

Site

There is no site work.

Foundations The foundation work shall be supplied, installed and built in accordance with Entergy specification and design drawings. Foundation installation recommendation specified in the Geotechnical Soils Report shall also form part of the installation requirement. The foundation scope of work includes design and constructs the following:

One (1) foundation for the new 138kV CCVT pedestal.

Three (3) foundations for the new 138kV lightning arrester.

Six (6) 2” PVC conduits will be installed from the existing circuit breakers 7900 and 7945 to the existing cable trough. Two (2) 2” PVC conduits will be installed from the new CCVT junction box to the existing cable trough. Approximately 150’ of new conduits will be installed from the cable trough to the equipment.

Replaced approximately 200’ of cable trough covers due to aging after cable installation.

Approximately 30’ of new precast cable trough will be installed to connect the two (2) cable entrances at the control house.

All new construction grounding including19 # 9 copperweld “pigtails” will be tied to the existing ground grid as per Entergy grounding standards.

Three (3) abandoned foundations will be removed for the new construction.


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Electrical

All equipment and structures shall be installed in accordance with Entergy specification and design drawings. The electrical scope of work includes design and constructs the following:

One (1) 138kV single phase line CCVT will be installed. The CCVT will be installed underneath the T-line and mounted on standard low bus equipment pedestal.

Three (3) lightning arresters will be installed and mounted on standard low bus equipment pedestal.

New strain bus/jumpers will be 954MCM ACSR (rated at 1089A).

Relaying

One (1) line/breaker control panel for line relaying and control of breaker associated with L-616 to Mossville and L-174 to Mossville.

Purchase and install one (1) CCVT for line potential per Entergy Standard PN0201, latest revision. CCVT to be purchased with carrier accessories for coordination and ease of construction purposes.

Relay Settings and Configuration

Develop relay settings for two (2) line/breaker control panels utilizing Entergy standard relays and referencing Entergy standard PM1803.

Review change in fault current levels and revise settings for all terminals leaving Orange, if necessary.


Long Delivery Items


1 Lot Substation Steels 10-12 weeks

3 Each 138kV Lightning Arrester 14-16 weeks


1 Each 138kV CCVTs 28 Weeks


Conduit will be installed from the control house out to breakers 7900 and 7945, and control cable will be pulled from the breaker into the control house. New cable trough and additional new cable trough covers will be installed, as well as a junction box. Old abandoned concrete foundations will be removed and four (3) new foundations poured. Grounding pigtails will be attached to the ground


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grid and run up to the new foundations to ground pedestals. One (1) CCVT and three (3) lightning arresters will be mounted on newly installed pedestals after the concrete has cured. This will be approximately six (6) weeks of pre-outage work. A new line/breaker control panel will be mounted inside the Nelson substation control house, and the existing line breakers 7900 and 7945 will be wired into the new panel. A two (2) week outage on L-616 will be required for the line panel swap and commissioning. This will have to coordinate with the line cut-in at Mossville substation to match relays on both ends, and for end-to-end checking. 954 mcm jumpers for the newly installed CCVT and lightning arrestors will also be completed during the same two week outage. New relay settings will be implemented and RTU configuration changes made.

4.7 Upgrade the PPG – Rose Bluff 230 kV transmission line

General The PPG-Rose Bluff 230 kV transmission line overloads for the loss of the Carlyss – Nelson 230 kV transmission line. It is required that the PPG-Rose Bluff 230 kV transmission line be upgraded from a capacity of 470 MVA to at least 482 MVA, 1210A. The equipment at PPG and Rose Bluff meet the new capacity specified in the solution set and no work is required at these substations.

Line Data Existing Line Rating 1180A Required Line Rating (Minimum) 1210A Proposed Line Rating (based on Equipment to be installed)

1303A

Affected line length in miles 2.0 miles

Line route

The scope of this project requests Line 696 to be upgraded to 1210 amps (482 MVA). This will require reconductoring the portion of the line with 1033 AAC to 1272 ACSR, and replacing 35 structures from the PPG to Rose Bluff substation situated in Calcasieu Parish, Louisiana. Reconductor the segment from PPG substation to structure 36. Remove existing shield wire and replace with 48 OPGW fibers.

ROW Existing ROW will be utilized. The line from PPG to Rose Bluff work can be performed under maintenance and we will need permits from LADOTD. Permit


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for crossing Bayou D’Inde from the Corps of Engineers may need to be updated. Environmental Permitting Environmental survey and SWPPP permit would be required. Structures and Foundations New structures will be designed to accommodate a single circuit of 1272 kcmil 45/7 ACSR code name “Bittern” conductor rated for 1303 amps (519 MVA) at 100 degrees Celsius in a delta/vertical configuration spaced for 230kV. All new dead-end structures foundation are assumed to be vibratory caisson and all new tangent structures foundation are assumed to be 15’ feet direct embedment backfill with crushed rock, unless otherwise noted. All design and construction will be completed in accordance with current Entergy loading, clearance and construction standards specifications for 230kV transmission line.

(3) New dead-end structures

(26) New tangent structures and

(4) New running angle tangent structures

Conductor and Insulators

83,000 lbs. of 1272 kcmil 45/7 ACSR “Bittern” conductor

(192) 230kV insulator

Shield Wire

33,500’ of 48 OPGW Fiber

18,500’ of 7 #7 Alumoweld shield wire

Long Delivery Items Quantity Unit Description Delivery time

35 Each Steel structures 18-20 weeks

5 Each Vibratory caissons 18-20 weeks

83,000 Pounds 1272 kcmil ACSR conductor 20-22 weeks

33,500 Feet 48 OPGW Fiber 26-28 weeks

18,500 Feet 7 #7 Alumoweld shield wire 26-30 weeks

192 Each 230kV Insulators 10-12 weeks


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Construction Methodology

If there is adequate room in the ROW, this line will be built alongside the current L-696 as Greenfield, and no outage will be required until it is time to tie the ends of the new line into the station and at structure 36. If clearance is an issue, then an outage will be requested on L-696, and the new line will be erected. This is an existing ROW, so no vegetation clearing is expected. Storm water controls will be installed before work begins and monitored throughout the project. Foundation work will be first by driving the vibratory caissons and backfilling with concrete. These will be allowed to cure for a minimum of seven (7) days. The tangent poles can be set while the foundations are curing. All structures will be set and framed out with dollies in preparation for wire pulling. Conductor and fiber will be pulled in and clipped and the drop into PPG substation secured as well as attaching to structure 36.

Outage Planning TOC will be asked to evaluate the outage availability of L-696 to determine if we can open the 230kV loop for an extended period or if we will need to work this line as piece work doing one (1) section at a time. Safety consideration and risks during construction Follow all Entergy and OSHA rules including EPZ and grounding requirements as well as clearance rules. An Entergy Operations Coordinator will be on site for a majority of the project.


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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. Entergy incurs a tax liability proportional to the amount of customer contributions.

Estimated Task Costs

2013 2014 Total

Cut-in Line 616 (Nelson – Carlyss 138 kV)

into Mossville 130 kV $ 228,541 $ 1,546,948 $ 1,775,489

Mossville Substation $ 543,285 $ 3,488,832 $ 4,032,117

Carlyss Substation $ 63,246 $ 314,869 $ 378,115

Bayou D’Inde Substation $ 75,576 $ 318,291 $ 393,866

Orange Substation $ 113,784 $ 360,401 $ 474,184

Nelson Substation $ 109,577 $ 554,904 $ 664,481

Upgrade the PPG – Rose Bluff 230 kV

transmission line $ 468,570 $ 3,174,109 $ 3,642,679

Total: $ 1,602,578 $ 9,758,354 $ 11,360,932

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 Reference

Cut-in Line 616 (Nelson – Carlyss 138

kV) into Mossville 130 kV $ 1,775,489 $ 1,775,489 4.1

Mossville Substation $ 4,032,117 $ 4,032,117 4.2

Carlyss Substation $ 378,115 $ 378,115 4.3

Bayou D’Inde Substation $ 393,866 $ 393,866 4.4

Orange Substation $ 474,184 $ 474,184 4.5

Nelson Substation $ 664,481 $ 664,481 4.6

Upgrade the PPG – Rose Bluff 230 kV

transmission line $ 3,642,679 $ 3,642,679 4.7

Total: $ 11,360,932 $ 7,718,253 $ 3,642,679


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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 ISD is projected to be November 30, 2014. Based on an assumed customer approval to proceed with the project by November, 2012, the following are approximate schedule dates:

Summary: Completed by:

Submit FS Jun-12

Receive permission to proceed with project Nov-12

Create FP/WO Dec-12

Complete PEP Jun-13

Customer approval + Revised FP approval Jul-13

Commence design/environmental study Aug-13

Start work on permits/order material Sep-13

Issue SS and line design for Construction Mar-13

Receive material Apr-13

Start construction May-14

Complete Construction Nov-14


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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.

**

Outages may not be available

Preliminary schedule only considers general outage constraints. Specific project schedule may be delayed by days, weeks or months dependant on system conditions. Delays of months = increased project costs.

**

Scope based on design assumptions which may change

Varied impact on cost and schedule. ***

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


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9. CONFIRMED RESERVATIONS

OASIS PSE MW Begin End

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


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

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

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

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








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


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



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

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

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

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

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

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





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




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




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

1498122 Constellation Energy Commodities Grp. 30 4/1/2012 4/1/2042

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



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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



1555717 (undesignation) East Texas Electric Cooperative 1 1/1/2010 1/1/2015




1557602 (undesignation) East Texas Electric Cooperative 1 1/1/2009 1/1/2017

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






1632265 (undesignation) 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


1665288 Merrill Lynch Commodities 15 1/1/2011 1/1/2017

1665492 (renewal) Merrill Lynch Commodities 16 11/1/2009 11/1/2014

1665493 (renewal) Merrill Lynch Commodities 4 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

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

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

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


73724303 Arkansas Electric Cooperative Corp. 104 1/1/2010 1/1/2015

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


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

73884547 MOWR 35 8/1/2010 8/1/2040

73884558 MOWR 40 8/1/2010 8/1/2040

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 (deferral) WRGS 15 4/1/2012 4/1/2017
















74728415 Brazos Electric Cooperative 100 1/1/2012 1/1/2017

74758974 (deferral) Entergy Services, Inc. (EMO) 804 5/1/2013 5/1/2058




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

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




















75265640 (renewal) South Miss Electric Power Assoc. 75 6/1/2011 6/1/2016

75299243 AECI 103 1/1/2012 1/1/2017

75342276 Cargill Power Markets 202 12/1/2012 12/1/2017

75342281 Cargill Power Markets 202 12/1/2012 12/1/2017

75460486 MOWR 103 4/1/2012 4/1/2037


75564309 ETEC 50 5/1/2014 5/1/2044


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75826033 CPWM 600 4/1/2014 4/1/2033

75831107 Muni Energy Agcy of Miss 20 6/1/2013 6/1/2041

76120007 (renewal) CLECO Power Marketing 10 10/1/2012 10/1/2017










76234993 76235000 76235003

Entergy Services (SPO) 475 1/1/2014 1/1/2043




76449800 Arkansas Electric Cooperative Corp.

250 1/1/2012 1/1/2013

275 1/1/2013 1/1/2014

300 1/1/2014 1/1/2015

320 1/1/2015 1/1/2017

76449828 Arkansas Electric Cooperative Corp.

78 1/1/2012 1/1/2013

80 1/1/2013 1/1/2014

82 1/1/2014 1/1/2015

84 1/1/2015 1/1/2016

86 1/1/2016 1/1/2017

76513126 (undesignation) Constellation Energy Commodities Grp. 1 1/1/2012 1/1/2017

76513148 (undesignation) Constellation Energy Commodities Grp. 1 1/1/2012 1/1/2017

76513215 EWOM 60 11/1/2009 11/1/2014

76513304 (renewal) EWOM 60 11/1/2014 11/1/2019

76533177 EWOM 25 4/1/2009 4/1/2014

76533260 (renewal) EWOM 25 4/1/2014 4/1/2019

76744580 (deferral) South Miss Electric Power Assoc. 2 1/1/2013 1/1/2040


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10. PRE-888 TRANSACTIONS

OASIS

PSE MW Begin End

1332606

East Texas Electric Cooperative 55 1/1/2006 1/1/2017

1412156

Entergy Services, Inc. (EMO) 741 1/1/2007 1/1/2038

1412158


1412160


1412161


1412162


1412164


1412165


1412166


1412167


1412168


1412169


1412171


1412172


1412173


1412175


1412176


1412178


1412179


1412181


1412183


1412184


1412185


1498278


1498281


1498283


1498284


1498285


1498286


1498287


1528114 Replaces 1412186


1528115 Replaces 1412177


1528116 Replaces 1412182


76120467 Renewal

for 1412178 Entergy Services, inc. (EMO) 61 1/1/2038 1/1/2045

76120472 Renewal

for 1412172 Entergy Services, inc. (EMO) 870 1/1/2038 1/1/2045

76120479 Replaces 1412155


76234797 Renewal

for 1412163 Entergy Services, Inc. (EMO) 194 1/1/2038 1/1/2043

76234817 Renewal


76234827 Renewal


76234836 Renewal


76292988 Replaces 1412163


76292990 Replaces 1412174


https://oasis.e-terrasolutions.com/OASIS/EES/data/transstatusdetails?ASSIGNMENT_REF=1332606&RETURN_TZ=CD































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OASIS

PSE MW Begin End

76292992 Replaces 1412170


76292993 Replaces 1412180


76528782 Constellation Energy Commodities Grp 5 7/1/1998 7/1/2027


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11. STUDY QUEUE

OASIS # PSE MW Begin End

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

75206836 ETEC 125 1/1/2015 1/1/2020

SPP 74240998_1004 _1007_1231_1265

AEP 20-116 1/1/2011 1/1/2020

SPP 75108838 Tenaska Power Services 6 8/1/2011 6/1/2014


SPP 75191922 AEP 70-73 6/1/2014 6/1/2019

SPP 75197442 Arkansas Electric Cooperative Corp. 170 6/1/2015 6/1/2020



76523750 SRMPA 180 6/1/2012 6/1/2018


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12. ATTACHMENTS

12.1 Table of Acronyms

Acronym Description

ACSR Aluminum Conductor Steel Reinforced

ACSS Aluminum Conductor Steel Supported

ADEQ Arkansas Department of Environmental Quality

AFUDC Allowance for Funds Used During Construction

ATC Available Transfer Capability

EES Entergy Control Area

EHV Extra-High Voltage

ERIS Energy Resource Interconnection Service

ICT Independent Coordinator of Transmission

IPO Independent Pole operated

ISD In-Service Date

kV Kilo-Volt

LADOTD Louisiana Department of Transportation & Development

MCM (M) Thousand Circular Mils

MVA Mega-Volt Amp

MW Mega-Watt

NPDES National Pollution Discharge Elimination System

NOI Notice of Intent

NRIS Network Resource Interconnection Service

OASIS Online Access and Same-time Information System

OATT Open Access Transmission Tariff

PEP Project Execution Plan

POD Point of Delivery

POR Point of Receipt

ROW Right-of-Way

SES Steam Electric Station

SOC System Operations Center

SHV Super High Voltage

SW Switch Station

SWPPP Storm Water Pollution Prevention Plan

TOC Transmission Operations Center

12.2 Drawings

Drawing Description Page

G8238EA1 Mossville 138/13.8 kV substation (electrical

arrangement) 33

G8238SO5 Mossville 138/69 kV substation (one-line) 34

G8157SO5 Carlyss 230/69 kV substation (one-line) 35

G8292SO5 Bayou D’Inde 138 kV substation (one-line) 36

G1132SO5 Orange 138 kV substation (one-line) 37

G8155SO5 Nelson 500/230/138 kV substation (one-line) 38

ON

138kV & 230kV BUSSES IS ABOVE 40kA."

"FOR SAFETY/G

ROUN

DIN

G PURPO

SES THE AVAILABLE FAULT CURRENT

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