Facilities Study Ictt-2010-149 Transmission Service

TRANSMISSION LINE & SUBSTATION PROJECTS

COMPANY:ENTERGY SERVICES, INC.

CUSTOMER: ENTERGY SERVICE INC, (SPO)

FACILITIES STUDY

EJO NO. F4PPMS0248

ICTT-2010-149

TRANSMISSION SERVICE FACILITIES STUDY REPORT

OASIS 74899996

Revision: 0

Issue Prepared Approved Rev Description of Revision Date By By Ibrahim Charles A 05/30/11 Submitted to TPD for input Khan Newell Rick Brian B 6/2/11 TPD Approval Bewley Warwick Sherri Ben 0 6/14/11 ICT Determines Upgrade Classification Maxey Roubique

OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

TABLE OF CONTENTS

1. PROJECT SUMMARY ...... 3 1.1 Background and Project Need ...... 3 1.2 Scope Summary ...... 3 1.3 Cost Summary ...... 5 1.4 Schedule Summary ...... 6

2. SAFETY REQUIREMENTS ...... 6

3. GENERAL ASSUMPTIONS ...... 6

4. SCOPE OF WORK ...... 7 4.1 Grimes Substation ...... 7 4.2 New Substation (NSS) – 230 kV ...... 18 4.3 Hartburg Substation – 500/230 kV ...... 25 4.4 New 230 kV line to New Substation from Hartburg ...... 34 4.5 Line Cut-in into New SS (Helbig to McLewis line) ...... 37 4.6 Line Cut-in New SS (Sabine to Georgetown lines) ...... 38 4.7 Sabine Substation – 230 kV ...... 40 4.8 Helbig Substation – 230 kV ...... 42 4.9 Georgetown Substation – 230 kV ...... 43

5. COST ...... 44

6. UPGRADE CLASSIFICATION ...... 45

7. SCHEDULE ...... 45

8. RISK ASSESSMENT ...... 47

9. CONFIRMED RESERVATIONS ...... 48

10. PRE-888 TRANSACTIONS ...... 52

11. STUDY QUEUE ...... 53

12. ATTACHMENTS ...... 54 12.1 Table of Acronyms ...... 54 12.2 One line & Substation Layout Drawing ...... 56

Page 2 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study 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 450 MW 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 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:

• Loblolly – Hammond: New 230 kV line – 2012 Expected ISD. • Bayou LaBoutte: Construct new 500-230 kV substation – 2011 Expected ISD. • Addis-Cajun: 230 kV line upgrade to 637 MVA. o Upgrade of Entergy owned equipment was completed in early 2011. o Upgrade of Louisiana Generating LLC owned equipment at Big Cajun #1 230 kV substation – Winter 2011 Expected ISD. • Jackson Miami Monument 115kV line: Upgrade line trap at Monument 115kV – 2011 Expected ISD.

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

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

Page 3 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study • Big Three - Carlyss 230 kV: Upgrade bus, switch, and jumpers at Carlyss 230 kV substation – 2011 Expected ISD. • Carlyss - Rose Bluff 230 kV line: Upgrade bus, switch, and jumpers at Carlyss 230 kV substation – 2011 Expected ISD.

1.2.3 2011-2014 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:

• Ray Braswell - Wynndale 115kV new line – 2013 Expected ISD.

1.2.4 Install a third 525 MVA, 345/138 kV autotransformer at Grimes

The Grimes 345/138 kV autotransformer #1 or #2 overloads for the loss of the Grimes 345/138 kV autotransformer #2 or #1. It is required that a third 525 MVA, 345/138 kV 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 0 MW.

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

1.2.5 Construct a new 230 kV substation; add a second 500/230 kV Hartburg autotransformer; and build a new 230 kV line from Hartburg 230 kV to the new 230 kV substation

The following constraints are observed for this transmission service request:

• Hartburg - Inland Orange - McLewis 230 kV FTLO Cypress - Hartburg 500 kV. • Cypress 500/138 kV autotransformer FTLO Cypress 500/230 kV autotransformer. • Cypress 500/230 kV autotransformer FTLO Cypress 500/138 kV autotransformer.

Page 4 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study It is required that the following project be constructed:

New 230 kV five (5) terminal substation

Re-route the McLewis - Helbig 230 kV transmission line (L-195) into the new five (5) breaker ring bus switchyard; connecting the McLewis and Helbig 230 kV substations to the new switchyard.

Re-route the Sabine-Georgetown 230 kV transmission line (L-572) into the new five (5) breaker ring bus switchyard; connecting the Sabine and Georgetown 230 kV substations to the new switchyard.

Hartburg – Install a second 800 MVA, 500/230 kV Autotransformer

The amount of capacity created by this upgrade is 800 MW, and the customer’s use of the capacity created is 27 MW.

Build a new 230 kV line from Hartburg 230 kV to the NSS.

The amount of capacity created by this upgrade is 1042 MW, and the customer’s use of the capacity created is 31 MW.

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

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

1.2.6 Financial Rights for Supplemental Upgrades

The following supplemental upgrade is impacted by this TSR by the specified MW amount.

• South Jackson-Florence 115 kV – 1 MW Impact o Estimated Unit Rate - $95,874/MW o Related Facilities Study – ASA-2008-001

1.3 Cost Summary

The estimated total project cost in 2011 dollars is $88,412,296. 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%).

Page 5 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study Financial Rights: As described in Section 1.2.6 above, $95,874 in financial rights payment will be required to the customer funding supplemental upgrades that were impacted by this transmission request. This does not include Tax Gross Up, which may be included.

The ICT has assigned $0 as Base Case upgrades and $88,316,422 as Supplemental Upgrade based on Attachment T of Entergy’s 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 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 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 based on only this Facilities Study and the associated 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 estimate in 2011 dollars and are based on existing data and could change considerably after development of a detailed PEP. 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.

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, and ground over current settings, etc. Some obsolete relays may need to be replaced.

Page 6 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study 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 Grimes Substation

Add a third 345/138 kV three-phase transformer with tertiary brought out for connecting reactors in future. The addition of this transformer requires the conversion of the existing 345 kV 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 345 kV equipment approximately 150’ x 800’. The existing eastern fence (approximately 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 ten (10) feet 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 six (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.

Page 7 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study • 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.

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 six (6) inches deep for at least ten (10) to twelve (12) feet around the equipment).

Foundations

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

• Install five (5) 345 kV Breaker foundations. • Install one (1) 345/138/13.8 kV 525 MVA autotransformer foundation with oil containment; • Install seven (7) 345 kV CCVT foundations; • Install three (3) 345 kV one-phase bus support foundations – high bus. • Install eighteen (18) 345 kV one-phase bus support foundations – low bus. • Install seventeen (17) 345 kV three-phase bus support foundations – high bus. • Install five (5) 345 kV three-phase bus support foundations – low bus. • Install five (5) 345 kV switch support foundations – high bus. • Install seven (7) 345 kV switch support foundations – low bus. • Install five (5) 150’ static tower foundations. • Install one (1) fire barrier wall foundation. • Install two (2) 345 kV reduced tension DE foundations. • Install three (3) 138 kV breaker foundations. • Install four (4) 138 kV switch support foundations – low bus. • Install one (1) 138 kV DE at auto (10AS52 type) foundation. • Install one (1) 138 kV DE at 138 kV Bay 11 (add-on). • Install 750’ of pre-cast cable trench near the new 345 kV 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.

Page 8 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study Electrical

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

• Install seven (7) 345 kV CCVT pedestals. • Install three (3) 345 kV one-phase bus supports – high bus. • Install eighteen (18) 345 kV one-phase bus supports – low bus. • Install seventeen (17) 345 kV three-phase bus supports – high bus. • Install five (5) 345 kV three-phase bus supports – low bus. • Install five (5) 345 kV switch support steel – high bus. • Install seven (7) 345 kV switch support steel – low bus (five (5) with insulator spacers). • Install five (5) 345 kV, 3000A, 40kA gas breakers. • Install one (1) 345/138/13.8 kV 525 MVA autotransformer. • Install seven (7) 345 kV CCVTs. • Install five (5) 345 kV, 2000A GOAB switches, with motor operators on low bus (three (3) on existing steel and two (2) on new steel). • Install five (5) 345 kV, 2000A GOAB switches, with motor operators on high bus. • Install 192 - 345 kV post insulators (90 for switches and 102 on bus/switch supports/DEs). • Install six (6) 345 kV suspension insulators at DEs for bundled 954 45/7 ACSR strung bus from 345 kV 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 five (5) 150’ static tower steel. • Install one (1) fire barrier wall. • Install two (2) 345 kV reduced tension DE structures. • Remove one (1) 36 MVAR, 138 kV capacitor bank and return to stores. • Install three (3) 138 kV, 3000A, 40 kA, gas breakers. • Install four (4) 138 kV switch support steel – low bus (two (2) with insulator spacers). • Install one (1) 138 kV DE at auto (10AS52 type) structure. • Install one (1) 138 kV DE at 138 kV Bay 11 (add-on). • Install two (2) 138 kV, 2000A, GOAB switches on low switch steel (Note: Spacing is 8’ center-to-center). • Install thirty (30) 138 kV post insulators (eighteen (18) for switches and twelve (12) for buses/DEs). • Install six (6) 138 kV polymer suspension insulators on DEs at 138 kV bay 11 and at auto transformer 138 kV DE. • Install 300’ of rigid 5” schedule 80 aluminum bus in 138 kV bays (954 45/7 ACSR damper). • Connect ground grid jumpers to structures and equipment.

Page 9 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study • Install 1,000’ of strung bus bundled 954 45/7 ACSR from autotransformer DE 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 (21) 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. • The existing battery charger #1 is a 50A model with 5.2A load, and the existing 440 Ah 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 200 Ah 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) 125 VDC Lead Acid Battery sets including two-step rack rated for a seismic zone 1, per Entergy Standard PM0203, latest revision. It is estimated that a 270 Ah set will be required. • All AC panels in use in the control house are not adequate to support the installation of the other twenty (20) additional panels. Purchase, design and install one (1) standalone 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 standalone 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 four (4) additional D20S cards with standard terminals will be required. It is estimated that two (2) additional D20 KI2 cards with standard terminations will be required. At present, there are two (2) K-boards and six (6) KI2 cards installed in the RTU. No additional K-board will be required. However, the cabinet appears maxed out and an additional

Page 10 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study 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 one (1) cyber security cabinet containing a Gauntlet secure port switcher, one SEL 2407 satellite clock, one Starcomm modem model number 240-0199, one (1) AC adapter, and all needed cables required for relay communications. • Purchase and install expansion equipment for the existing DFR.

345 kV/138 kV Autotransformer #3 Protection

• Purchase, design, and install one (1) autotransformer panel using an Entergy approved standard if available or Lewis Creek 230 kV substation as a reference. 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 current transformers (CTs) of the 345 kV breaker bushings to the bus/line node side CTs of the 138 kV 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 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 345 kV CTs of the autotransformer to the bus side CTs of the 345 kV 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 138 kV CTs of the autotransformer to the bus/line node side CTs of the 138 kV 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 345 kV CVT with carrier accessories per Entergy standard PN0201, latest revision. This CVT will be used for hot 345 kV node indications, 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.

Page 11 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

345 kV/138 kV autotransformer #1 protection

345 kV/138 kV autotransformer #2 protection

• Install one (1) new 345 kV CVT with Carrier accessories per Entergy standard PN0201, latest revision. This CVT will be used for hot 345 kV node indications, 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. • Reconfiguration of the 345 kV 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 138 kV 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 138 kV CTs of the autotransformer to the bus side CTs of the 138 kV circuit breakers. This bus differential panel will function as backup protection of the low side portion of the large zone autotransformer protection.

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

Page 12 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

345 kV 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 345 kV CVTs with Carrier accessories per Entergy standard PN0201, latest revision. These CVTs will be used for hot 345 kV bus indications, 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.

138 kV 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 three (3) new 138 kV 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 138 kV circuit breakers will be required.

138 kV Mt. Zion Line 485 (existing 138 kV 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 138 kV CVTs with Carrier accessories per Entergy standard PN0201, latest revision. These CVTs will be used for hot 138 kV line node indications, 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.

Page 13 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

Existing 138 kV Equipment

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

• 138 kV 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 5 345 kV breaker 28-32 wks 3 138 kV breaker 14-16 wks 1 345 kV/138 kV 525 MVA autotransformer 26-32 months 10 345 kV GOAB vertical Break switch 18-20 wks 2 138 kV GOAB vertical Break switch 14-16 wks Multiple 138 kV & 345 kV Steel 18-20 wks 192 345 kV post insulators 11-14 wks 6 345 kV suspension insulator 10-12 wks 30 138 kV post insulators 11-14 wks 6 138 kV 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 1 Cyber Security Cabinet 12-14wks 1 Autotransformer Diff Panel 12-14wks 7 Bus Diff Panel 12-14wks 9 345 kV CVTs 20-22wks 3 138 kV 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 one-liner. • Provide relay settings for new primary and backup transformer differential relays for Transformer #3 (T-Pro and SEL 387-6). • 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).

Page 14 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study • 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 (four (4) sets of settings). • Provide relay settings for five (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 (SEL 321).

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 five (5) new 138 kV breaker control panels.

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).

Page 15 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

Remote Station Revisions

Due to fault current increases caused by the addition of the third autotransformer at Grimes, revisions of ground over current relaying at fourteen (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 four (4) 345 kV breaker foundations and one (1) 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 will be erected. The breakers will be set and the transformer will be brought in. The transformer

Page 16 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study 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 345 kV bus can be done without an outage requirement. Two (2) 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, two (2) CCVTs will be installed, one (1) new 345 kV GCB and two (2) new 345 kV switches will be installed. A new 138 kV 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 345 kV GCB and one 345 kV switch. During this time, two (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 138 kV 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.

Page 17 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

Remote station revisions: If the setting revisions can not be accomplished, replacement of relays will be required. Until 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 cannot 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 five (5) weeks in duration and will open the South Bus at Grimes – devices 16800, 26175, and T2. • The second outage will be three (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 (1) week. • The fourth outage is L485 Grimes to Mt Zion with duration of three (3) weeks. • The fifth outage is for the East bus at Grimes and is two (2) weeks in duration. • Outage 1, 4, and 5 all must be coordinated 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.

4.2 New Substation (NSS) – 230 kV

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

• Re-route the McLewis-Helbig 230 kV transmission line (L-195) into the new five breaker ring bus switchyard; connecting the McLewis and Helbig 230 kV substations to the new switchyard. • Re-route the Sabine-Georgetown 230 kV transmission line (L-572) into the new five breaker ring bus switchyard; connecting the Sabine and Georgetown 230 kV substations to the new switchyard. • New breakers at the New SS need to have an interrupting rating of least 27 kA. Require at least 3000A, 40kA IPO breakers. • 63 KA 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.

Page 18 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study New SS 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 SS 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.

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.

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 40 kA fault currents and 63 kA breakers are not required – IPO breakers are required – 63 kA breakers will be used since the costs are the same as the 50kA breakers. • Substation bus is rated 4500A (6” Schedule 40 aluminum tubing) for both the West and East bus and 3000A (4” Schedule 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.

Page 19 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

New 230 kV Substation – Proposed site location

The proposed new 230 kV substation site is located on the northern side of the ROW intersection of Line 195 and Line 572. The size of this property is 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 (less than 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:

Page 20 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study 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 four (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.

Foundation Work

Foundation Work will include installation of the following:

• Two (2) pull boxes on one side of the control house. • 450’ cable trough (including two (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’). • One (1) 20’ x 40’ Control House foundation. • Five (5) 230 kV, 60’ A-frame DE foundations (Four (4) legs/ DE). • 24 – 230 kV, one-phase bus support (low bus) foundations. • Six (6) 230 kV, one-phase bus support (hi bus) foundations. • 18 – 230 kV, Switch Support (Low Bus) foundations (Two (2) legs/ support). • 15 – 230 kV, CCVT Support Pedestal foundations. • 15 – 230 kV, LA Support Pedestal foundations. • Five (5) 230 kV, IPO Breaker foundations. • Two (2) 230 kV, 100KVA SSVT foundations. • Nine (9) yard lighting foundations.

Page 21 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

Electrical Work

Electrical Work will include installation of the following:

• One (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). • Five (5) 230 kV, 60’ A-frame DE. • 24 – 230 kV, one-phase Bus Support (low bus). • Six (6) 230 kV, one-phase Bus Support (hi bus). • 18 – 230 kV, Switch Support (low bus – one (1) with BK1 brackets for insulators). • 15 – 230 kV, CCVT support pedestal. • 15 – 230 kV, LA support pedestal. • Two (2) 230 kV, 100KVA SSVT support structures. • Two (2) 230 kV, 100KVA SSVTs. • Five (5) 230 kV, 3000A, 63kA, IPO Breaker. • 12 – 230 kV, 3000A, GOAB Switch. • Five (5) 230 kV, 2000A, GOAB switch with ground switch. • 15 – 230 kV, CCVTs (purchased by relaying). • 15 – 230 kV, surge arresters. • Nine (9) Two (2) fixture, HPS yard lights. • 153 – 230 kV porcelain post insulators for switches. • 63 – 230 kV high strength polymer insulators for bus supports and DEs (30 for 1 ph bus supports, 3 for switch stand, 30 for DE structures). • Two (2) 240/120 V, 400A fusible safety switches.

List of Major Equipment

Qty Item Lead Time 450’ Cable Trough 8-10 weeks 2,500’ 4” Aluminum Tubular Bus Schedule 40 10-12 weeks 1,100’ 6” Aluminum Tubular Bus Schedule 40 10-12 weeks 2 Pull Boxes 1 20’ x 40’ Control House 14-16 weeks 5 230 kV, 60’ H-frame DE 20-24 weeks 24 230 kV, one-phase Bus Support (Low Bus Structure 10-12 weeks 6 230 kV, one-phase Bus Support (Hi Bus) Structure 10-12 weeks 18 230 kV, Switch Support (Low Bus) Structure(1 with BK1 10-12 weeks brackets) 15 230 kV, CCVT Support Pedestal Structure 10-12 weeks 15 230 kV, LA Support Pedestal Structure 10-12 weeks 2 230 kV, 100KVA SSVT Support structures 16-18 weeks 2 230 kV, 100KVA SSVTs 24-28 weeks 5 230 kV, 3000A, 63kA, IPO Breaker 14-16 weeks

Page 22 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study 12 230 kV, 3000A, GOAB Switch 14-16 weeks 5 230 kV, 3000A, GOAB Switch w/Ground Switch 14-16 weeks 15 230 kV, CCVTs (purchased by relaying) 18-29 weeks 15 230 kV, Surge Arresters 14-16 weeks 63 230 kV, Insulator, Polymer 10-12 weeks 153 230 kV, 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 two-step rack rated for a seismic zone 1. It is estimated that a 200 Ah 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. 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 230 kV 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 230 kV substation.

Page 23 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study • 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 230 kV 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 L-X SEL 421 primary relay at the Hartburg substation. • Establish protective relay telecommunications circuits between Hartburg and NSS for L-X. 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 230 kV L-X to Hartburg. • Install fifteen (15) new 230 kV 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

Delivery Quantity Description time 2 125VDC Battery Set 12-14 weeks 1 AC Panel 12-14 weeks 2 DC Panel 12-14 weeks 5 Line/Breaker ctrl panel 12-14 weeks 1 RTU 12-14 weeks 1 Digital microwave equipment 20-22 weeks 15 230 kV CVTs 20-22 weeks

Page 24 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

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.

Construction methodology

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. Entergy assumes that the duration of substation work to be approximately four (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 two (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.

4.3 Hartburg Substation – 500/230 kV

• Install new 800 MVA, 500/230 kV autotransformer. • Construct Hartburg 230 kV ring bus and expand Hartburg 500 kV 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 (800 MVA). • No reactive compensation is required for the tertiary. However, units will have a tertiary winding for future reactor applications. • New breakers at Hartburg 230 kV need to have an interrupting rating of at least 23kA. Require at least 3000A, 40kA IPO breakers. • New breakers at Hartburg 500 kV need to have an interrupting rating of at least 25kA. Require at least 3000A, 40kA IPO breakers.

Environmental Permitting

Page 25 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study 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.

230 kV Ring Bus Area

A new 230 kV transmission line termination point will be installed in the existing 230 kV switchyard at Hartburg Substation. This will be accomplished by transforming the existing 230 kV substation area into a four (4) breaker ring bus configuration (area is configured to be a breaker and a half scheme). The existing Helbig transmission line and 500/230 kV #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 two 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 47 kA 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.) • 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 in tact 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

Page 26 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study 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:

• Four (4) 230 kV circuit breaker foundation MM1, as per drawing G1167F12. • Four (4) 230 kV switch support foundation per new tubular switch structure design (16’ spacing). (Note: Each switch support foundation consists of two separate footings.) • Nine (9) 230 kV single-phase bus support foundation (new tubular design). • Seven (7) 230 kV CVT support foundation (new tubular design). • Six (6) 230 kV station class surge arrester foundations. • One (1) 230 kV A-frame DE using 16’ spacing. (Note: Each DE foundation consists of four (4) separate footings.) • 45 – 19#9 copperweld “pigtails” for structures and equipment – estimated quantity approximately 30’ per pigtail – 1350’ total). • 230’ of pre-cast cable trough near northeast bay of ring bus. • 1,000’ of new 2” conduits (280’ for the seven (7) new CCVTs and 720’ for the four (4) breakers – six (6) new conduits per breaker averaging 30’ each). • 1,120’ of conduit trench for above conduits. • 2,500 tons limestone surfacing for ring bus area (200’ x 360’).

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). • One (1) 230 kV A-frame DE structure (could be H-frame). • Four (4) 230 kV 3000A, 63kA, IPO breakers. (Note: Existing switch structures have 12’ spacing, while new structures are 16’ spacing.) • Four (4) 230 kV switch supports low bus (new design - 16’ spacing). • Five (5) 230 kV 3000A vertical break disconnect switches with 12’ spacing on existing structures. (Note: Existing line has a ground switch already installed.) (Note: Center break switches may be required.) • Four (4) 230 kV 3000A vertical break disconnect switches with 16’ spacing. (One (1) with ground switch for the new line).

Page 27 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study (Note: Center break switches may be required.). • Six (6) 230 kV surge arresters structures (new tubular design). • Six (6) 230 kV station class surge arresters. • Seven (7) 230 kV CVT support structures (new tubular design). • Seven (7) 230 kV CVT. • Nine (9) 230 kV single-phase bus supports (new tubular design). • 81 – 230 kV porcelain post insulators for switches. • 27 – 230 kV polymer insulators for the bus supports and DEs.

Long Lead Items

Qty Item Lead Time 230’ Cable Trough 8-10 weeks 2,500’ 4” Aluminum Tubular Bus Schedule 40 10-12 weeks 1 230 kV, 60’ A-frame DE 20-24 weeks 9 230 kV, one-phase Bus Support (Low Bus) Structure 10-12 weeks 4 230 kV, Switch Support (Low Bus) Structure 10-12 weeks 7 230 kV, CCVT Support Pedestal Structure 10-12 weeks 6 230 kV, LA Support Pedestal Structure 10-12 weeks 4 230 kV, 3000A, 63kA, IPO Breaker 14-16 weeks 8 230 kV, 3000A, GOAB Switch 14-16 weeks 1 230 kV, 3000A, GOAB Switch w/Ground Switch 14-16 weeks 7 230 kV, CCVT’s (purchased by relaying) 18-29 weeks 6 230 kV, Surge Arresters 14-16 weeks 27 230 kV, Insulator, Polymer 10-12 weeks 81 230 kV, Insulator, Porcelain 10-12 weeks

500 kV/230 kV Autotransformer Area

The location for the new autotransformers is actually to be located where transformers were removed in the past. Site photos show existing bus work for 500 kV, 230 kV 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 four (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 230 kV DE to the individual single-phase autotransformer DEs are in tact and useable.

Page 28 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

Foundation Work

Foundation Work will include installation of the following:

• Four (4) 500 kV/230 kV/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 one (1) barrier wall to isolate spare). • 1 - 500 kV IPO breaker foundations, 3000A, 63kA. • 2 - 500 kV, 3000A, GOAB, vertical break switch foundations. • 3 - 500 kV CVT support foundations. • Four (4) 500 kV surge arrester support foundations. • Four (4) 230 kV surge arrester support foundations. • 2,000’ of new 2” conduits for 500 kV CVTs, breaker, motor operators and autotransformers). • 750’ of conduit trench for above conduits. • 60 – 19#9 copperweld “pigtails” for structures and equipment – estimated quantity approximately 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 - 500 kV/230 kV/13.8kV single-phase auto-transformers, 160/212/267MVA (wye w/ delta tertiary) • 1 - 500 kV IPO breaker foundations, 3000A, 63kA • 2 - 500 kV, 3000A, GOAB vertical break, with 125VDC motor operator • 22 – 500 kV 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 - 500 kV CVT support structures (new octagonal design) • 3 - 500 kV CVT • Four (4) 500 kV surge arrester support structures • Four (4) 230 kV surge arrester support structures • Four (4) 500 kV surge arrester for autotransformers • Four (4) 230 kV surge arrester for autotransformers

Long Lead Items

Qty Item Lead Time 3 500 kV/230 kV/13.8kV single-phase auto-transformers, 26-32 Months 160/212/267MVA 1 500 kV IPO breaker foundations, 3000A, 63kA 28-32 Wks 2 500 kV, 3000A, GOAB vertical break, with 125VDC motor 14-16 Wks

Page 29 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study operator 22 500 kV porcelain post insulators 24-26 Wks 3 500 kV CVT support structures (new octagonal design) 20-22 Wks 3 500 kV 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 4 500 kV surge arrester support structures 10-12 Wks 4 230 kV surge arrester support structures 10-12 Wks 4 500 kV surge arrester 14-16 Wks 4 230 kV surge arrester 14-16 Wks

Relay

The Hartburg relay drawing file contains over 250 Hartburg 500 kV and 230 kV 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 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 230 kV 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 L-X SEL 421 primary relay at the NSS substation. • Establish protective relay telecommunications circuits between Hartburg and NSS for L-X. 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 230 kV L-X to Hartburg. • In addition to the OPGW fiber installed in the shield position on new 230 kV L-X from NSS to Hartburg, an approximately four mile ADSS underbuild circuit will be installed on the Echo to Front Street line from the 230 kV 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.

Page 30 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study • 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 using an Entergy approved standard if available for the new differential relay or Lewis Creek 230 kV Substation as a reference. 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 500 kV breaker bushings to the line side autotransformer 230 kV 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 500 kV CTs of the autotransformer to the line node side CTs of the 500 kV circuit breakers. The low side bus differential panel will wrap from the low side 230 kV CTs of the autotransformer to the line node side CTs of the 230 kV circuit breakers. These bus differential panels will function as backup protection of the high and low side portions of the large zone autotransformer protection. • 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 using an Entergy approved standard if available for the new differential relay or Lewis Creek 230 kV Substation as a reference. 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 500 kV breaker bushings to the line side autotransformer 230 kV 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 500 kV CTs of the

Page 31 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study autotransformer to the line node side CTs of the 500 kV circuit breakers. The low side bus differential panel will wrap from the low side 230 kV CTs of the autotransformer to the line node side CTs of the 230 kV 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 230 kV 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 500 kV 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 500 kV and 230 kV circuit breakers. • Complete design of the AC and DC control schematics as well as the monitoring alarms for the new 500 kV and 230 kV circuit breakers will be required.

Long Lead Items

Quantity Description Delivery time 5 Breaker Control Panel 12-14wks 2 Line relay panel 12-14wks 2 Autotransformer Diff Panel 12-14wks 4 Bus Diff Panel 12-14wks 7 230 kV CVTs 20-22wks 3 500 kV CVTs 20-22wks

Relay settings

Develop relay settings for transformer, line and breakers.

RTU Configuration

Develop RTU configuration and display of equipment and control at TOC

Construction methodology

• Install 2nd auto (T1) with 1 new 500 kV 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, 500 kV

Page 32 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study ring can be put back to normal until 2nd auto (T1) is ready for connection to new 230 kV bus. • Install 3 new 230 kV breakers, north bus CVT’s and replace all switches except existing L195 line switch while making all bus connections on north half of new 230 kV ring bus to low side of New T1. • New T1 connections low side to new north bus of 230kV 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 230 kV 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 230 kV 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 230 kV 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 230 kV 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 230 kV Bus). L195 may need to be out completely, if only briefly while the Helbig end is opened and load swap over to new Hartburg 230 kV 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 230 kV SS 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 SS at L195 and L572 intersection.

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

Assuming above scenario:

• New T1 node/500 kV 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.

Safety consideration and risks during construction

Live substation work and proximity of 500 kV 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

Page 33 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study discussed in relay scope documentation to prevent inadvertent load drops (McLewis and Inland Orange taps).

4.4 New 230 kV line to New Substation from Hartburg

The above drawing shows the location of the new 230 kV sub along with the proposed cut-ins of L572, 195 and the new 230 kV 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 230 kV sub on the east side.

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

Line Data MVA Required Line Rating (Minimum) 1150 MVA Proposed Line Rating (based on 1190 MVA Equipment to be installed) Affected line length 15 mi

Page 34 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study 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.

Structures and Foundations

The 15 mile line from Hartburg to NSS 230 kV will require the installation of approximately 119 new concrete poles and 11 steel poles. Self-supporting steel DEs 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 DE structures.

Conductor and Insulators

• The line will require the installation of approximately 432 insulator assemblies. • The line will require the installation of approximately 936,700 lbs of bundled 1590 ACSR “Lawping” conductor. • OPGW wire will be used for shield wire. It will be terminated on splice boxes on the DE structure. Approximately 88,000 lbs of 48-fiber “Alumocore” OPGW will be used. • 7#7 will be used as the shield wire on spans that require a second shield wire. Approximately 550’ will be installed.

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 transmission 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.

Page 35 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study 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. • 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 $25,000 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.

Long Delivery Items

Quantity Material Description *Lead Time (weeks) 119 Poles, Concrete 10 weeks 11 Poles, Steel 18 weeks 936,700 Conductor 2-1590” 22 weeks 88,000 Cable, OPGW, 48-Fiber Alumocore 16 weeks 432 Insulator Assemblies 14 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.

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Outage Planning

• None required for new line if conductor at Hartburg is installed over south 230 kV 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.

Safety consideration during construction

Multiple parallel lines with multiple crossings, requiring guard structures and discussion of EPZ and proper grounding requirements.

4.5 Line Cut-in into New SS (Helbig to McLewis line)

Line Data MVA Required Line Rating 685 MVA (Minimum) Proposed Line Rating (based on Equipment to be 780 MVA installed) 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 230 kV 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 230 kV 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.

Structures and Foundations

The cut-in to the NSS 230 kV will require the installation of approximately 2 new concrete poles and 4 steel poles. Self-supporting steel DEs 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 DE structures.

Page 37 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study Conductor and Insulators

• 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.

Long Delivery Items

Quantity Material Description *Lead Time (weeks) 2 Poles, Concrete 10 weeks 4 Poles, Steel 18 weeks 21,450 lbs Conductor, 1272 “Bittern” ACSS 22 weeks 36 Insulator Assemblies 14 weeks

Construction methodology for new line construction

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.

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

Line Data MVA Required Line Rating 685 MVA (Minimum) Proposed Line Rating (based on Equipment to be 780 MVA installed) Affected line length 4,500’

Page 38 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

Line route

The new substation will be placed north of the intersection of L195 and L572. L572 will cut-in and out of the 230 kV 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 230 kV 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.

Structures and Foundations

The cut-in to the NSS 230 kV will require the installation of approximately 3 new concrete poles and 3 steel poles. Self-supporting steel DEs 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 DE structures.

Conductor and Insulators

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.

Long Delivery Items

Quantity Material Description *Lead Time (weeks) 3 Poles, Concrete 10 weeks 3 Poles, Steel 18 weeks 19,300 lbs Conductor, 1272 “Bittern” ACSS 22 weeks 33 Insulator Assemblies 14 weeks

Construction methodology for new line construction

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.

Page 39 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

Outage Planning

L572 – Sabine to Georgetown – 5 days.

4.7 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. 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 – 230 kV GCB or OCB breaker foundations • Install 8 – 230 kV, 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 – 230 kV GCB or OCB breakers • Install 8 – 230 kV, 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.

Page 40 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

Long Lead Items

Qty Item Lead Time 8 230 kV, 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 230 kV and 138 kV 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 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 230 kV 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 230 kV circuit breakers will be required.

Long Delivery/Major Material Items

Quantity Description Delivery time 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

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Construction methodology

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.

Safety consideration and risks during construction

Live substation work and proximity of 230 kV 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.

4.8 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

Quantity Description Delivery time 1 Digital microwave equipment 20-22wks 1 Line/Breaker Control Panel 12-14wks

Relay settings

Develop relay settings for the new panel.

Page 42 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

Construction methodology

See Line cut in to NSS Section 4.5.

4.9 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 work order.

Relay settings

Develop relay settings for line to new SS.

Construction methodology

See Line cut in to NSS 4.6.

Note: The cost for this task is included in the Sabine - Georgetown cut in described in section 4.6.

Page 43 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

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.

2011 2012 2013 2014 Total Grimes add transformer $ 87,699 $ 407,792 $ 18,541,375 $ 5,631,940 $ 24,668,806 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 $ 549 $ 12,772 $ 674,666 $ 520,107 $ 4,926,868 Line cut-in to New SS $ 2,470 $ 16,467 $ 42,322 $ 719,928 $ 781,187 McLewis - Helbig line Line cut-in to New SS Sabine $ 2,470 $ 16,467 $ 58,541 $ 734,404 $ 811,883 to Georgetown line Hartburg - New SS Line $ 25,331 $ 814,522 $ 6,971,619 $ 9,188,078 $ 16,999,550 Total $ 174,750 $ 2,064,952 $ 45,759,026 $ 36,598,921 $ 88,316,422

Page 44 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study 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 4.1 Hartburg $ 28,962,485 $ 28,962,485 4.3 New SS $ 10,559,832 $ 10,559,832 4.2 Helbig $ 605,811 $ 605,811 4.8 Sabine $ 4,926,868 $ 4,926,868 4.7 Line cut-in to New SS $ 781,187 $ 781,187 4.5 McLewis - Helbig line Line cut-in to New SS $ 811,883 $ 811,883 4.6 Sabine to Georgetown line Hartburg - New SS Line $ 16,999,550 $ 16,999,550 4.4 South Jackson - Florence $ 95,874 $ 95,874 1.2.6 Total: $ 88,412,296 $ 88,316,422 $ 95,874

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. • 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.

Page 45 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study • 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 • Transformers - as their delivery would take 32 months would arrive in November 2014. • Secure ROW and permits for New Substation (NSS), line cut-ins by November 2013 (reason – CCN permits) • 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. • Construct Grimes Substation starting for completion by December 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 months for transformers/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.

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 Scope and estimate for new ROW is based on limited knowledge of individuals ROW and Permits **** using the aerial views, etc on the internet and could vary considerably Rising steel, copper, fuel and other Material costs steel & Equipment market conditions could greatly affect **** estimated cost. Best guess on SWPPP creation, implementation and monitoring can vary Storm-water plan implementation ** greatly dependant on outcome of environmental study. Unexpected delays on material lead times, unusually inclement weather will Weather & Equipment Lead Times ** impact schedule but might impact AFUDC costs as well. Undetermined until environmental Wetland mitigation *** analysis is complete. Preliminary schedule only considers general outage constraints. Specific project schedule may be delayed by days, Outages may not be available ** weeks or months dependant on system conditions. Delays of months = increased project costs. The selected site may not be available by the time easement or purchase of substation site is required. A new site Uncertainty of ability to secure substation site may have to be picked impacting on the *** and line cut-in Row for new SS 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 Need revision to schedule * than assumed in developing schedule Impact would be on completion date – Transformer delivery could be delayed due to could be delayed by several months to a ** failure in testing or problems in transportation year. Prices could be higher at the time of Cost of transformer and IPP breakers ** placing the order Scope based on design assumptions which Varied impact on cost and schedule. *** may change *-low impact to cost, ** - moderate impact to cost, ***- high impact to cost, **** - very high

Page 47 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

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 759196 Entergy Services, Inc. (EMO) 143 1/1/2001 1/1/2021 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 1105665 Entergy Services, Inc. (EMO) 236 2/1/2003 2/1/2016 1105666 Entergy Services, Inc. (EMO) 91 2/1/2003 2/1/2027 1105668 Entergy Services, Inc. (EMO) 77 2/1/2003 2/1/2027 1126821 Entergy Services, Inc. (EMO) 101 5/1/2004 5/1/2029 1151106 Entergy Services, Inc. (EMO) 20 6/1/2010 6/1/2029 1168061 Entergy Services, Inc. (EMO) 80 8/1/2004 2/1/2028 1168408 Entergy Services, Inc. (EMO) 247 8/1/2004 2/1/2028 1289686 (undesignation) Entergy Services, Inc. (EMO) 1 6/1/2007 6/1/2030 1294132 Entergy Services, Inc. (EMO) 526 1/1/2006 1/1/2035 1309874 (renewal) East Texas Electric Cooperative 75 1/1/2009 1/1/2017 1309875 (renewal) East Texas Electric Cooperative 50 1/1/2009 1/1/2017 1309876 (renewal) East Texas Electric Cooperative 50 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 1381400 Constellation Energy Commodities Grp. 34 1/1/2006 1/1/2036 1381404 Constellation Energy Commodities Grp. 17 1/1/2006 1/1/2036 1381406 Constellation Energy Commodities Grp. 17 1/1/2006 1/1/2036 1383852 Arkansas Electric Cooperative Corp. 550 1/1/2007 1/1/2017 1385158 NRG Power Marketing 13 10/1/20070 10/1/2027 1387272 CLECO Power LLC (Gen) 11 4/1/2006 4/1/2016 1410022 Constellation Energy Commodities 60 3/1/2010 3/1/2040 1422708 (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2007 1/1/2027 1425495 East Texas Electric Cooperative 50 3/1/2010 3/1/2045 1437089 Arkansas Electric Cooperative Corp. 349 1/1/2007 1/1/2012 1440189 Arkansas Electric Cooperative Corp. 84 1/1/2008 1/1/2012 1440190 Arkansas Electric Cooperative Corp. 104 1/1/2008 1/1/2012 1442453 NRG Power Marketing 320 6/1/2007 6/1/2026 1449495 Entergy Services, Inc. (EMO) 322 6/1/2009 6/1/2059 1456636 CLECO Power Marketing 10 10/1/2007 10/1/2012 1460876 Aquila Networks-MPS 75 3/1/2009 3/1/2029 1460878 Aquila Networks-MPS 75 3/1/2009 3/1/2029 1460879 Aquila Networks-MPS 75 3/1/2009 3/1/2029 1460881 Aquila Networks-MPS 75 3/1/2009 3/1/2029 1460898 Louisiana Energy & Power Authority 3 1/1/2009 1/1/2030 1460899 Louisiana Energy & Power Authority 5 1/1/2009 1/1/2030

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OASIS PSE MW Begin End 1461442 Louisiana Energy & Power Authority 12 1/1/2009 1/1/2030 1464028 East Texas Electric Cooperative 168 1/1/2010 1/1/2040 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 1470811 East Texas Electric Cooperative 186 1/1/2010 1/1/2040 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 1477069 Entergy Services, Inc. (EMO) 10 11/1/2007 11/1/2037 1480164 Entergy Services, Inc. (EMO) 725 1/1/2005 9/1/2033 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 1499610 Entergy Services, Inc. (EMO) 300 1/1/2008 1/1/2038 1500582 (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2008 1/1/2038 1500584 (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2008 1/1/2038 1502952 Arkansas Electric Cooperative Corp. 330 1/1/2008 1/1/2030 1514102 East Texas Electric Cooperative 29 1/1/2008 1/1/2017 1514104 East Texas Electric Cooperative 35 1/1/2008 1/1/2017 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 1525820 (renewal) NRG Power Marketing 3 7/1/2009 7/1/2014 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 1546108 (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2011 1/1/2051 1552148 (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2009 1/1/2014 1555717 (undesignation) East Texas Electric Cooperative 1 1/1/2010 1/1/2015 1555718 Entergy Services, Inc. (EMO) 158 1/1/2010 1/1/2015 1557220 (undesignation) Entergy Services, Inc. (EMO) 1 7/1/2009 7/1/2018 1557221 Entergy Services, Inc. (EMO) 520 7/1/2009 7/1/2018 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 1564356 (renewal) NRG Power Marketing 5 9/1/2009 9/1/2025 1566302 NRG Power Marketing 300 1/1/2008 1/1/2013 1585225 (renewal) City of Prescott 22 4/1/2009 4/1/2039 1585239 (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2009 1/1/2013 1585240 (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2009 1/1/2013 1598022 (renewal) NRG Power Marketing 103 7/1/2010 7/1/2015 1598291 Entergy Services, Inc. (EMO) 206 6/1/2012 6/1/2042 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 1602650 NRG Power Marketing 5 7/1/2010 7/1/2020 1615102 (renewal) MidAmerican Energy, Inc. 50 1/1/2009 1/1/2014 1615103 MidAmerican Energy, Inc. 50 1/1/2009 1/1/2014 1615105 MidAmerican Energy, Inc. 50 1/1/2009 1/1/2014 1615108 MidAmerican Energy, Inc. 50 1/1/2009 1/1/2014 1629240 MidAmerican Energy, Inc. 7 3/1/2009 3/1/2014 1630065 NRG Power Marketing 40 1/1/2010 1/1/2015

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OASIS PSE MW Begin End 1632265 Merrill Lynch Commodities 1 4/1/2009 4/1/2014 1632268 Merrill Lynch Commodities 25 4/1/2009 4/1/2014 1633701 NRG Power Marketing 20 1/1/2010 1/1/2019 1633702 NRG Power Marketing 20 1/1/2010 1/1/2016 1633703 NRG Power Marketing 20 1/1/2010 1/1/2016 1639337 Entergy Services, Inc. (EMO) 587 3/1/2009 1/1/2019 1639338 Entergy Services, Inc. (EMO) 103 3/1/2009 1/1/2019 1639339 Entergy Services, Inc. (EMO) 32 3/1/2009 1/1/2019 1639340 Entergy Services, Inc. (EMO) 122 3/1/2009 1/1/2019 1639341 Entergy Services, Inc. (EMO) 134 3/1/2009 1/1/2019 1640629 CLECO Power Marketing 58 5/1/2001 1/1/2021 1640630 CLECO Power Marketing 32 5/1/2001 1/1/2021 1643983 (renewal) NRG Power Marketing 300 1/1/2010 1/1/2015 1643984 (renewal) NRG Power Marketing 100 9/1/2010 9/1/2015 1644155 CLECO Power Marketing 9 4/1/2009 5/1/2016 1644215 NRG Power Marketing 83 1/1/2010 1/1/2025 1644908 CLECO Power Marketing 41 5/1/2009 5/1/2018 1648049 (undesignation) Entergy Services, Inc. (EMO) 1 6/1/2010 6/1/2013 1648050 Entergy Services, Inc. (EMO) 100 6/1/2010 6/1/2013 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 1658087 (undesignation) Entergy Services (SPO) 1 6/1/2012 6/1/2042 1658088 SMEPA 21 6/1/2012 6/1/2042 1659388 NRG Power Marketing 25 1/1/2011 1/1/2016 1665168 (renewal) Merrill Lynch Commodities 60 11/1/2009 11/1/2014 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 1668165 Entergy Services (SPO) 600 1/1/2013 1/1/2043 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 1676674 NRG Power Marketing 100 1/1/2011 1/1/2020 1676675 NRG Power Marketing 100 1/1/2011 1/1/2020 1677749 (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2013 1/1/2015 1679179 (renewal) NRG Power Marketing 100 1/1/2011 1/1/2016 1679181 (renewal) NRG Power Marketing 100 1/1/2011 1/1/2016 1682716 (renewal) NRG Power Marketing 206 1/1/2011 1/1/2012 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 1690613 NRG Power Marketing 25 1/1/2011 1/1/2016 1694305 Entergy Services (SPO) 15 5/1/2010 5/1/2020 1694306 Entergy Services (SPO) 30 5/1/2010 5/1/2020 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 73595626 NRG Power Marketing 13 1/1/2012 1/1/2017

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OASIS PSE MW Begin End 73659139 NRG Power Marketing 50 5/1/2010 5/1/2011 73723105 Arkansas Electric Cooperative Corp. 270 1/1/2010 1/1/2015 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 73741122 (renewal) Entergy Services, Inc. (EMO) 135 5/1/2010 5/1/2020 73774729 Arkansas Electric Cooperative Corp. 84 1/1/2010 1/1/2015 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 73987480 South Miss Electric Power Assoc. 100 5/1/2010 5/1/2040 73987507 South Miss Electric Power Assoc. 180 6/1/2010 6/1/2015 73990804 South Miss Electric Power Assoc. 100 5/1/2010 5/1/2040 74001787 NRG Power Marketing 100 1/1/2011 1/1/2016 74001895 NRG Power Marketing 100 1/1/2011 1/1/2016 74001897 NRG Power Marketing 22 1/1/2011 1/1/2016 74001904 NRG Power Marketing 28 1/1/2011 1/1/2016 74001930 NRG Power Marketing 42 8/1/2006 8/1/2036 74001931 NRG Power Marketing 60 3/1/2010 3/1/2040 74001934 NRG Power Marketing 60 4/1/2012 4/1/2042 74233619 WRGS 15 4/1/2012 4/1/2017 74233670 (undesignation) Entergy Services, Inc. (EMO) 1 8/1/2012 1/1/2038 74236787 NRG Power Marketing 75 6/1/2012 6/1/2017 74236794 NRG Power Marketing 100 6/1/2012 6/1/2017 74236798 NRG Power Marketing 100 6/1/2012 6/1/2017 74305315 NRG Power Marketing 10 1/1/2014 1/1/2017 74305339 NRG Power Marketing 10 1/1/2013 1/1/2023 74356639 NRG Power Marketing 103 1/1/2011 1/1/2016 74356652 NRG Power Marketing 206 6/1/2012 6/1/2017 74356666 NRG Power Marketing 50 1/1/2013 1/1/2014 74370625 NRG Power Marketing 10 7/1/2010 7/1/2012 74514903 Entergy Services, Inc. (EMO) 20 6/1/2013 6/1/2029 74514911 Entergy Services, Inc. (EMO) 101 6/1/2013 6/1/2029 74691007 NRG Power Marketing 60 1/1/2013 1/1/2018 74758974 Entergy Services, Inc. (EMO) 804 5/1/2013 5/1/2058 74777205 (renewal) NRG Power Marketing 300 1/1/2013 1/1/2033 74777208 (renewal) NRG Power Marketing 300 1/1/2015 1/1/2035 74789476 (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2012 1/1/2016 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 74899954 (undesignation) Entergy Services, Inc. (EMO) 1 2/1/2012 2/1/2014 74899956 Entergy Services, Inc. (EMO) 100 2/1/2012 2/1/2014 74899968 (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2013 1/1/2015 74899969 (undesignation) Entergy Services, Inc. (EMO) 1 1/1/2012 1/1/2015

Page 51 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study

10. PRE-888 TRANSACTIONS

OASIS PSE MW Begin End 1332606 East Texas Electric Cooperative 55 1/1/2006 1/1/2017 1412155 Entergy Services, Inc. (EMO) 1718 1/1/2007 1/1/2038 1412156 Entergy Services, Inc. (EMO) 741 1/1/2007 1/1/2038 1412158 Entergy Services, Inc. (EMO) 1867 1/1/2007 1/1/2038 1412160 Entergy Services, Inc. (EMO) 1142 1/1/2007 1/1/2038 1412161 Entergy Services, Inc. (EMO) 59 1/1/2007 1/1/2038 1412162 Entergy Services, Inc. (EMO) 148 1/1/2007 1/1/2038 1412163 Entergy Services, Inc. (EMO) 194 1/1/2007 1/1/2038 1412164 Entergy Services, Inc. (EMO) 1157 1/1/2007 1/1/2038 1412165 Entergy Services, Inc. (EMO) 1219 1/1/2007 1/1/2038 1412166 Entergy Services, Inc. (EMO) 683 1/1/2007 1/1/2038 1412167 Entergy Services, Inc. (EMO) 140 1/1/2007 1/1/2038 1412168 Entergy Services, Inc. (EMO) 456 1/1/2007 1/1/2038 1412169 Entergy Services, Inc. (EMO) 739 1/1/2007 1/1/2038 1412170 Entergy Services, Inc. (EMO) 183 1/1/2007 1/1/2038 1412171 Entergy Services, Inc. (EMO) 64 1/1/2007 1/1/2038 1412172 Entergy Services, Inc. (EMO) 870 1/1/2007 1/1/2038 1412173 Entergy Services, Inc. (EMO) 129 1/1/2007 1/1/2038 1412174 Entergy Services, Inc. (EMO) 140 1/1/2007 1/1/2038 1412175 Entergy Services, Inc. (EMO) 130 1/1/2007 1/1/2038 1412176 Entergy Services, Inc. (EMO) 65 1/1/2007 1/1/2038 1412177 Entergy Services, Inc. (EMO) 947 1/1/2007 1/1/2038 1412178 Entergy Services, Inc. (EMO) 61 1/1/2007 1/1/2038 1412179 Entergy Services, Inc. (EMO) 304 1/1/2007 1/1/2038 1412180 Entergy Services, Inc. (EMO) 351 1/1/2007 1/1/2038 1412181 Entergy Services, Inc. (EMO) 692 1/1/2007 1/1/2038 1412182 Entergy Services, Inc. (EMO) 1641 1/1/2007 1/1/2038 1412183 Entergy Services, Inc. (EMO) 433 1/1/2007 1/1/2038 1412184 Entergy Services, Inc. (EMO) 1926 1/1/2007 1/1/2038 1412185 Entergy Services, Inc. (EMO) 946 1/1/2007 1/1/2038 1412186 Entergy Services, Inc. (EMO) 1233 1/1/2007 1/1/2038 1498278 Entergy Services, Inc. (EMO) 75 8/1/2007 1/1/2017 1498281 Entergy Services, Inc. (EMO) 86 8/1/2007 1/1/2017 1498283 Entergy Services, Inc. (EMO) 68 8/1/2007 1/1/2017 1498284 Entergy Services, Inc. (EMO) 78 8/1/2007 1/1/2017 1498285 Entergy Services, Inc. (EMO) 11 8/1/2007 1/1/2044 1498286 Entergy Services, Inc. (EMO) 69 8/1/2007 1/1/2044 1498287 Entergy Services, Inc. (EMO) 14 8/1/2007 1/1/2044

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11. STUDY QUEUE

OASIS PSE MW Begin End 74597193 NRG Power Marketing 300 1/1/2013 1/1/2018 74597198 NRG Power Marketing 300 1/1/2013 1/1/2018 74728369 Brazos Electric Cooperative 100 1/1/2012 1/1/2017 74728395 Brazos Electric Cooperative 100 1/1/2012 1/1/2017 74728400 Brazos Electric Cooperative 100 1/1/2012 1/1/2017 74728415 Brazos Electric Cooperative 100 1/1/2012 1/1/2017 74728420 Brazos Electric Cooperative 100 1/1/2012 1/1/2017 74799834 Cargill Power Markets 101 7/1/2012 7/1/2017 74799836 Cargill Power Markets 101 7/1/2012 7/1/2017 74799837 Cargill Power Markets 101 7/1/2012 7/1/2017 74799848 Cargill Power Markets 101 7/1/2013 7/1/2018 74799851 Cargill Power Markets 101 7/1/2013 7/1/2018 74799853 Cargill Power Markets 101 7/1/2013 7/1/2018 74846159 AEPM 65 1/1/2015 1/1/2020 74899933 Entergy Services (SPO) 322 2/1/2011 2/1/2041 74899972 (undesignation) Entergy Services (SPO) 1 1/1/2015 1/1/2045 74899974 (undesignation) Entergy Services (SPO) 1 1/1/2015 1/1/2045 74899976 (undesignation) Entergy Services (SPO) 1 1/1/2015 1/1/2045 74899980 Entergy Services (SPO) 584 1/1/2015 1/1/2045 74899988 (undesignation) Entergy Services (SPO) 1 6/1/2012 6/1/2042 74899989 Entergy Services (SPO) 485 6/1/2012 6/1/2042

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12. ATTACHMENTS

12.1 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 CU Cubic CVT Current Voltage Transformer CYDS Cubic Yards 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 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 Amperes LA Lightening Arrestor MCM (M) Thousand Circular Mils MITC Methylisothiocyanate MOS Motor Operated Switch MUST Managing and Utilizing System Transmission MVA Mega-Volt Amp MW Mega-Watt NEPA National Environmental Policy Act 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

Page 54 of 56 OASIS 74899996 Entergy Services, Inc. (SPO) Facilities Study 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 TSR Transmission Service Request USACE United States Army Corps of Engineers VDC Voltage Direct Current WO Work Order WOTAB West Of The Atchafalaya Basin

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12.2 One line & Substation Layout Drawing

One Lines

GXXXXSO5 NSS 230kV (New Switch Station) Page 57 G1207SO5 Georgetown 230kV Substation Page 58 G1136SO5 Helbig Bulk 230kV Substation Page 59 G1167SO5 Hartburg 500kV Substation Sh-1 Page 60 G1167SO6 Hartburg 500kV Substation Sh-2 Page 61 G1710SO5 McLewis 230/34.5kV Substation Page 62 G1259SO6 Inland Orange 230kV Substation Page 63 G2143SO6 Sabine 230/138kV Substation Sh-2 Page 64 G2143SO7 Sabine 230/138kV Substation Sh-3 Page 65

Substation Layouts

G1167EA2 Hartburg 500kV Substation Page 66 G1167EA4 Hartburg 500kV Substation (Addition) Page 67 G2143EA4 Sabine 230/138kV Substation Page 68 GXXXXEA1 NSS 230kV Switchyard Page 69

Duration Schedules

Duration Schedule Summary Page 70

Page 56 of 56 H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\one-lines\GXXXXSO5 - NSS.DWG, 4/25/2011 1:34:36 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/GROUNDING PURPOSES THE AVAILABLE FAULT CURRENT IS ABOVE 40kA." IS ABOVE CURRENT FAULT AVAILABLE THE PURPOSES SAFETY/GROUNDING "FOR 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/GROUNDING PURPOSES THE AVAILABLE FAULT CURRENT IS ABOVE 40kA." IS ABOVE CURRENT FAULT AVAILABLE THE PURPOSES SAFETY/GROUNDING "FOR 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 H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\Sabine\G2143EA4-Sabine.DWG, 4/25/2011 2:11:32 PM, lbernad H:\A-Louber\Current-WIP-1313\2011\JET-PEPs\Active\Oasis #74900000\NSS\GXXXXEA1 - NSS.dwg, 4/25/2011 2:02:00 PM, lbernad 2011 end of Feb Mar April May June July Aug Sept Oct Nov Dec Customer + FP 0 0 4 4 4 4 Approval 4 4

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

Revised FP approval + order commence customer transformers/IPO design/ROW/enviro Order all Complete PEP approval breakers mental material

2013 Jan Feb Mar April May June July Aug Sept Oct Nov Dec

Issue design for construction - Issue design for NSS/line cut- Construct Receive material construction - ins/Hartburg line + Commence complete Grimes, Mt including IPO Grimes/Mt Zion relay design for line Construction ROW/CCN + Zion, NSS, & bkrs but XFMRs line + Sabine end Substations at Sabine environmental Hartburg line

2014 Jan Feb Mar April May June July Aug Sept Oct Nov Dec

Complete Const including Grimes, McLewis, Helbig, Receive George Town transformers and Sabine