TRANSMISSION / DISTRIBUTION PROJECTS
COMPANY:EAI CUSTOMER: ENTERGY SERVICES (EMO) FACILITIES STUDY EJO # F4PPAR0437
ICTT-2007-184
TRANSMISSION SERVICE REQUEST OASIS 1500580
Revision: 2
Issue Project Rev Description of Revision Revised By Date Manager 0 1/25/08 Issued for Review to ICT GWR 1 2/04/08 ICT Determines Upgrade Classification JDL JH 2 2/11/08 Updated Costs JDL JH
EMO OASIS 1500580 Facilities Study
1. EXECUTIVE SUMMARY ...... 5
2. SAFETY AWARENESS...... 5
3. SCOPE SUMMARY ...... 6 I. Sarepta Project:...... 6 1) Louisiana...... 6 2) Arkansas ...... 6 II. Install a 2nd 500/115kV Autotransformer at McNeil ...... 8 III. Overload of Magnolia South-Shuler 115kV Transmission Line for the loss of the El Dorado 500/115 kV Autotransformer ...... 8 IV. Add a 30.5 MVAR Capacitor Bank at Prescott 115kV Substation for Voltage Support...... 8 4. SCOPE DETAILS ...... 9 I. Sarepta Project:...... 9 1) Louisiana...... 9 2) Arkansas ...... 9 3) Additional Substations...... 9 II. McNeil Substation – Add Second 500/115 kV Autotransformer ...... 9 III. Upgrade Magnolia South to Shuler 115 kV Line to at least 176 MVA (16.28 Miles) ...... 9 1) Additional Substation...... 9 IV. Add a 30.5 MVAR Capacitor Bank at Prescott 115kV Substation for Voltage Support...... 9 V. Detailed Scopes ...... 9 1) Construct a 345/115 kV tie at Sarepta 115kV Substation...... 9 2) Upgrade Minden-Minden Bulk 115kV Transmission Line...... 10 3) Install a 36 MVAR Capacitor Bank at Lucky 115kV,...... 11 4) Install a 28.8 MVAR Capacitor Bank at Vienna 115kV ...... 12 5) Install a 21.6 MVAR capacitor bank at Emerson 115kV ...... 13 6) Minden Substation...... 13 7) Minden Bulk (Cajun) Substation ...... 14 8) Longwood Substation (SWEPCO)...... 14 VI. McNeil Substation – Add Second 500/115 kV Autotransformers...... 14 VII. Upgrade Magnolia South to Shuler 115kV line to at least 176 MVA...... 15 1) Magnolia South Substation (885 amps) ...... 15 2) Shuler Substation (885 amps)...... 15 VIII. Prescott Substation (Add 30.5 MVAR Capacitor Bank)...... 15 5. COSTS ...... 16
Entergy Transmission Business Page 2 of 24 EMO OASIS 1500580 Facilities Study 6. SCHEDULE...... 17
7. CONFIRMED RESERVATIONS ...... 18
8. STUDY QUEUE ...... 22
9. ATTACHMENTS ...... 24 1) Location Drawings...... 24 2) One Line Drawings...... 24 3) Sarepta Project Execution Plan...... 24
Entergy Transmission Business Page 3 of 24 EMO OASIS 1500580 Facilities Study Acronyms Used in this Study AECI Associate Electric Cooperatives, Incorporated AFC Allowable Flowgate Capacity ATC Available Transfer Capability ICT Independent Coordinator of Transmission EES Entergy Control Area MVA Mega-Volt Amp MW Mega-Watt OASIS Online Access and Same-time Information System OATT Open Access Transmission Tariff TSR Transmission Service Request TTC Total Transfer Capability WPP Weekly Procurement Process
Entergy Transmission Business Page 4 of 24 EMO OASIS 1500580 Facilities Study 1. EXECUTIVE SUMMARY
The purpose of this Facilities Study is to determine the transmission improvements needed to un-designate the study generator as a network generator for Entergy native load. This request from Entergy Services (EMO) is for 1MW of yearly network transmission service. The time period for this transfer is from 1/1/2008 until 1/1/2038. The direction of the transaction is EES to EES. This study was performed on the latest available 2012 summer peak case, using PSS/E and MUST software by Power Technologies Incorporated (PTI).
Some of the upgrades detailed in this facility study were identified in a higher queued Transmission Service Request. The OASIS numbers, for those requests, are listed with each upgrade. If that prior request is not Confirmed, responsibility for funding this upgrade (in accordance with Entergy's OATT) will be required under this request. If the prior request is confirmed and the customer enters into a Transmission Service Agreement with Entergy, the responsibility to fund the upgrade will be a requirement under the prior request; however the funding party will have Financial Transmission Rights (FTRs) to any additional capacity created by the upgrade in accordance with Attachment T to Entergy's OATT. Use of any available capacity created as a result of that upgrade will require payment to the funding party for use of those FTRs in accordance with Attachment T.
The facility study identifies any transmission constraints resulting from the requested power transfer. The facility study also includes cost estimates to correct any transmission constraints.
Under Entergy’s Independent Coordinator of Transmission which became effective on November 17, 2006, Entergy will recover these costs based on the Attachment T to our OATT. Based on Attachment T, the ICT has determined these costs to be classified as Base Plan and Supplemental Upgrades.
2. SAFETY AWARENESS
Safety is a priority with Entergy. Safety will be designed into substations and lines. The designs will be done with the utmost safety for personnel in mind for construction, operation and maintenance of the equipment.
All employees working directly or indirectly for Entergy shall adhere to all rules and regulations outlined within the Entergy Safety manual. Entergy requires safety to be the highest priority for all projects. All Entergy and Contract employees must follow all applicable safe work procedures.
Entergy Transmission Business Page 5 of 24 EMO OASIS 1500580 Facilities Study 3. SCOPE SUMMARY The Facilities Study has identified some transmission constraints. The constraints can be addressed in the following manner:
I. Sarepta Project: 1) Louisiana • Construct a 345/115 kV tie at Sarepta 115kV substation • Upgrade Minden-Minden Bulk 115kV transmission line • Install a 36 MVAR capacitor bank at Lucky 115kV, • Install a 28.8 MVAR capacitor bank at Vienna 115kV. 2) Arkansas • Install a 21.6 MVAR capacitor bank at Emerson 115kV
Constraints were identified for this transmission service request which will be alleviated by the 2011 Southwest Arkansas/Northwest Louisiana Reliability Improvement project (Sarepta project) in the 2008 ICT Base Plan and proposed in Entergy’s 2008-2010 Transmission Construction Plan. This project has not yet been approved. If this project is approved, the customer will only be required to fund acceleration costs as the thermal and voltage constraints are seen during 2009. The acceleration costs cannot be determined at this time.
The proposed Sarepta project will solve thermal and under-voltage constraints listed below:
Thermal Overloads Limiting Element Contingency Element Vienna-TRussell Crossing 115kV Magnolia East-McNeil 115kV Haynesville-Sarepta 115kV Arcadia-TRussell Crossing 115kV Vienna-TRussell Crossing 115kV McNeil 500/115kV autotransformer El Dorado Donan-El Dorado EHV 115kV Camden Maguire-Smackover 115kV El Dorado East-El Dorado Jackson 115kV El Dorado Monsanto-El Dorado Donan 115kV El Dorado East-El Dorado EHV 115kV El Dorado Donan-El Dorado EHV 115kV Vienna-TRussell Crossing 115kV Magnolia East-Magnolia Steel-Kerlin 115kV Vienna-TRussell Crossing 115kV Danville-Jonesboro 115kV Vienna-TRussell Crossing 115kV Minden-Ada-Sailes 115kV Sailes-Ada 115kV Vienna-TRussell Crossing 115kV El Dorado Monsanto-El Dorado Donan 115kV El Dorado East-El Dorado Jackson 115kV El Dorado Donan-El Dorado EHV 115kV El Dorado East-El Dorado Jackson 115kV El Dorado EHV-El Dorado Donan-El Dorado Monsanto 115kV Vienna-Bernice 115kV El Dorado EHV 500/115kV autotransformer
Entergy Transmission Business Page 6 of 24 EMO OASIS 1500580 Facilities Study Under-Voltages
Substation Contingency Element L.A. Ordinance Plant 115kV McNeil 500/115kV autotransformer Minden 115kV Cullen 115kV Haynesville 115kV Sarepta 115kV Springhill 115kV Emerson 115kV Taylor 115kV Prescott 115kV Kerlin 115kV Kerlin SS 115kV Hope North 115kV Magnolia Steel 115kV Emmett 115kV Hope East 115kV Magnolia Dow 115kV Ada 115kV Magnolia East 115kV Lamartine 115kV Beirne 115kV Magnolia West 115kV Magnolia South 115kV McNeil 115kV Couch 115kV Gurdon 115kV Gurdon North AECC 115kV Arcadia 115kV Richwoods North AECC 115kV Shuler 115kV Lewisville 115kV Hope North 115kV Arkadelphia North-Richwoods North AECC 115kV Emmett 115kV Hope East 115kV Prescott 115kV Gurdon-Gurdon North AECC 115kV Hope East 115kV Arkadelphia North-Friendship 115kV Prescott 115kV Richwoods North AECC-Gurdon North AECC Beirne 115kV 115kV Gurdon North AECC 115kV Gurdon 115kV Hope North 115kV Emmett 115kV Prescott 115kV Gurdon-Beirne 115kV Beirne 115kV Hope North 115kV Emmett 115kV Magnolia Dow 115kV Magnolia East-McNeil 115kV Magnolia East 115kV Magnolia Steel 115kV Kerlin 115kV Kerlin SS 115kV Emerson 115kV Haynesville 115kV Cullen 115kV Sarepta 115kV
Entergy Transmission Business Page 7 of 24 EMO OASIS 1500580 Facilities Study Springhill 115kV Taylor 115kV Kerlin 115kV Magnolia Steel-Kerlin 115kV Kerlin SS 115kV Emerson 115kV Haynesville 115kV Prescott 115kV Harvey Couch SES-McNeil 115kV Hope North 115kV Emmett 115kV Cullen 115kV
II. Install a 2nd 500/115kV Autotransformer at McNeil
The El Dorado 500/115kV autotransformer overloads for the loss of the McNeil 500/115kV autotransformer. It is required that a 2nd 500/115kV autotransformer at McNeil with a capacity of 600 MVA be installed.
III. Overload of Magnolia South-Shuler 115kV Transmission Line for the loss of the El Dorado 500/115 kV Autotransformer
The Magnolia South-Shuler 115kV transmission line overloads for the loss of the El Dorado 500/115kV autotransformer. The Magnolia South-Shuler 115kV transmission line needs to have a capacity of 141 MVA or greater on all components. The line conductor has a rated capacity of 176 MVA, but the Shuler 115kV switch #B0558 is rated at 600A or 120 MVA. The switch needs to be upgraded to 1200A.
IV. Add a 30.5 MVAR Capacitor Bank at Prescott 115kV Substation for Voltage Support
A 30.5 MVAR capacitor bank is needed for voltage support at the following substations:
Substation Contingency Element Friendship 115kV Hot Springs EHV-Friendship 115kV Richwoods North AECC 115kV Gurdon North AECC 115kV Gurdon 115kV Arkadelphia North 115kV Prescott 115kV Beirne 115kV Hope North 115kV Emmett 115kV Hope East 115kV Richwoods North AECC 115kV Arkadelphia North-Friendship 115kV Gurdon North AECC 115kV Gurdon 115kV Prescott 115kV Beirne 115kV Hope North 115kV Emmett 115kV Arkadelphia North 115kV
Entergy Transmission Business Page 8 of 24 EMO OASIS 1500580 Facilities Study The 30.5 MVAR capacitor bank also resolves the following thermal constraints. Limiting Element Contingency Element Hope East-Harvey Couch SES 115kV Hot Springs EHV-Friendship 115kV Hope East-Harvey Couch SES 115kV Arkadelphia North-Friendship 115kV
Detail scopes & estimates will be provided for the upgrades listed. Each upgrade recommended under Section 1 - Sarepta Project will be developed and grouped as a project.
4. SCOPE DETAILS
I. Sarepta Project: 1) Louisiana • Construct a 345/115 kV tie at Sarepta 115kV substation • Upgrade Minden-Minden Bulk 115 kV transmission line to 176 MVA • Install a 36 MVAR capacitor bank at Lucky 115kV, • Install a 28.8 MVAR capacitor bank at Vienna 115kV. 2) Arkansas • Install a 21.6 MVAR capacitor bank at Emerson 115kV 3) Additional Substations • Minden Substation (885 amps) • Minden Bulk (Cajun) Substation (885 amps) II. McNeil Substation – Add Second 500/115 kV Autotransformer III. Upgrade Magnolia South to Shuler 115 kV Line to at least 176 MVA (16.28 Miles) 1) Additional Substation • Magnolia South Substation (885 amps) • Shuler Substation (885 amps) IV. Add a 30.5 MVAR Capacitor Bank at Prescott 115kV Substation for Voltage Support
V. Detailed Scopes 1) Construct a 345/115 kV tie at Sarepta 115kV Substation This project has been identified as a reliability improvement project and a full Project Execution Plan (PEP) has been developed. In completion of the PEP additional tasks were identified. The detailed scopes are included in attachment and will not be detailed in this study. However, the additional tasks will be shown and cost data provided.
Entergy Transmission Business Page 9 of 24 EMO OASIS 1500580 Facilities Study Tasks for new 345/115 kV autotransformer at Sarepta
Sarepta 115 kV Substation Upgrade Sarepta 345/115 kV New Substation El Dorado Relay Upgrades S345 to S115 T-Line 345kv Line Cut In Longwood Substation Rely Review
2) Upgrade Minden-Minden Bulk 115kV Transmission Line Requirement is to increase capacity from 80 MVA to 176 MVA or greater. The line length is 5.1 miles and will be rebuilt because the original construction was not designed for the larger conductor size and does not meet existing loading and clearance standards for the new conductor.
Scope of Line Design • Remove 5.2 miles of wood H-frame transmission line including poles, insulators, conductors, shield wire, guy wire, etc. • Install 5.2 miles of single pole, single circuit transmission line using 666 ACSR Flamingo conductor, polymer insulators, 24 fiber 0.528” dia. OPGW shield wire, and vibratory pile foundations where required.
ROW or Permit issue known at this time: • Utilize existing ROW • No known permitting issues at the time of this scope.
Long Delivery items with lead times:
Quantity Material Description *Lead Time (weeks) 53 Poles 16 22 Foundation 16 24,000 lbs 666 MCM ACSR “Flamingo” cable 22 28,000 ft OPGW Shield Wire 14 225 Insulator assembles 12
Construction Methodology, duration of construction and outages required: • Mobilize line contractor and receive materials. • Take a 32 week outage on Minden-Minden Bulk line section. • Rebuild line with new structures, insulators, conductor and OPGW shield wire. • Total construction duration – approximately 35 weeks.
Assumptions made in scoping and estimates: • No Distribution underbuild • Foundations will be needed on approximately 40% of the structures
Entergy Transmission Business Page 10 of 24 EMO OASIS 1500580 Facilities Study 3) Install a 36 MVAR Capacitor Bank at Lucky 115kV, A 36 MVAR capacitor bank (fuse-less, ungrounded wye) will be installed at Lucky Substation in ELI. The capacitor bank will be installed on the 115 kV bus on the west side of the Transformer #141 bay.
Site Work • Soil borings will be required. • The capacitor bank will be installed on the NW corner of the substation. The existing north and west fence line will have to be expanded. This will require removal of approximately 215 feet of fence and the subsequent addition of approximately 275 feet of new fence and one new 20’ gate. • The ground grid will be enlarged to accommodate the station expansion. • A topographical survey will be required for station expansion.
Foundation Work • Install one “CE” tower drilled-pier foundations for disconnect switch. • Install one 36MVAR capacitor bank drilled-pier foundation. • Install two 3-phase bus support drilled-pier foundations (two piers pre structure). • Install one foundation (two drilled piers) for CapSwitcher. • Install three CVT pedestal drilled-pier foundations. • Install ~500’ of 4/0 copper perimeter ground around new fence
Electrical Work • Install one 36MVAR capacitor bank, fuseless, 115kV, ungrounded wye. • Install one 16’ “CE” tower. • Install one 121kV, 2000A, 125VDC, CapSwitcher. NOTE: The CapSwitcher contains pre-insertion resistors. Transmission System Planning would have to determine the size of the PI resistor based on future system requirements. • Install one 2000A vertical break gang operated air break switch between the circuit switcher and operating bus. • Install two 3-phase bus supports. • Install 3 CVT pedestals. • Install fifteen 115kV station post insulators. • Install ~250 ft. 2 ½ inch rigid aluminum bus.
Relay Work • Install one (1) ungrounded wye capacitor bank control panel (125VDC) • Install three (3) 115kV CCVT’s • Install one (1) 69kV S&C potential device • Install two (2) potential junction boxes • Install one (1) LOT of control cable • Install one (1) Modem • Verify points on RTU D-20 - Install analog card & indication/control • Install circuit breakers in existing AC Panel.
Entergy Transmission Business Page 11 of 24 EMO OASIS 1500580 Facilities Study • Install 400 Amp Trap for capacitor bank.– Bank on the line w/PLC
Settings • Calculate and Develop Relay Settings for the new Capacitor Bank Relays. • SCADA Configurations
4) Install a 28.8 MVAR Capacitor Bank at Vienna 115kV A 28.8 MVAR capacitor bank (fuse-less, ungrounded wye) will be installed at Vienna Substation in ELI.
Site Work • The capacitor bank will be installed on the 115 kV bus in the north- east corner of the substation adjacent to the Wyatt line bay. There is an existing capacitor bank foundation in the substation but it is unknown if it can be re-used. • The ground grid should be sufficient since there was once a cap bank in this location. Additional material may be required if the ground grid does not meet the current grounding standard. • Some limestone dressing may be required after construction is completed.
Foundation Work • Install one “CE” tower drilled-pier foundations for disconnect switch. • Install one 28.8 MVAR capacitor bank drilled-pier foundation. • Install three lally column bus support foundations. • Install one foundation (two drilled piers) for CapSwitcher.
Electrical Work • Install one 28.8 MVAR capacitor bank, fuseless, 115kV, ungrounded wye. • Install one 16’ “CE” tower. • Install one 121kV, 2000A, 125VDC, CapSwitcher. NOTE: The CapSwitcher contains pre-insertion resistors. Transmission System Planning would have to determine the size of the PI resistor based on future system requirements. • Install one 2000A vertical break gang operated air break switch between the circuit switcher and inspection bus. • Install three lally column bus supports. • Install twelve 115kV station post insulators. • Install ~150 ft. 2 ½ inch rigid aluminum bus.
Relay Work • Install one (1) ungrounded wye capacitor bank control panel (125VDC) • Install one (1) 69kV S&C potential device • Install two (2) potential junction boxes
Entergy Transmission Business Page 12 of 24 EMO OASIS 1500580 Facilities Study • Install one (1) LOT of control cable • Install one (1) Modem • Verify points on RTU D-20 - Install analog card & indication/control • Install circuit breakers in existing AC Panel.
Settings • Calculate and Develop Relay Settings for the new Capacitor Bank Relays. • SCADA Configurations
5) Install a 21.6 MVAR capacitor bank at Emerson 115kV Scope of Work: • Install (1) 21.6 MVAR Cap Bank with foundation • Install (1) Circuit Switcher with foundation • Install (1) Vertical Break GOAB with structure and foundation Relay Work: • Purchase and install one (1) Ungrounded Capacitor Bank control panel using the ZIV relay. • Purchase and install (1) 115kV, 200A Line trap pre-tuned to 166 kHz. • Purchase and install one (1) 69kV Resistive Potential Device. • Purchase and install one (1) resistive potential device junction box. • Purchase and install one split AC/DC panel. • Sarepta line relaying will now companion trip the capacitor bank for a line fault. • Purchase and install 10000 ft of control cable. • Replace existing Camco RTU with new GE Harris D20.
6) Minden Substation Scope of Work: This includes upgrading underrated breaker, switches, CCVT, line trap and associated bus.
Electrical: • Install (1) 2000A GCB to replace breaker R3938 • Install (2) 2000A disconnect switches. • Install (1) 115kV Ground switch • Replace bus conductors, jumpers & fittings etc.
Relay • Design breaker connection diagram for upgraded breaker R3983 • Purchase and install one (1) 115kV, 2000A line trap • Purchase and install one (1) 115kV CCVT • Purchase and install one (1) line tuner. • Purchase and install approximately 5000 ft of new control cables • Purchase and install one (1) RTU status card
Entergy Transmission Business Page 13 of 24 EMO OASIS 1500580 Facilities Study 7) Minden Bulk (Cajun) Substation This substation is owned by Cajun and any upgrades will be determined by the owner.
8) Longwood Substation (SWEPCO) The line protection relays at Longwood be reviewed and upgrades determined by the owner.
VI. McNeil Substation – Add Second 500/115 kV Autotransformers A second set of 500/115 kV 200 MVA autotransformers will be installed in the substation. The existing three breaker ring will be expanded to a four breaker ring. The existing autotransformer terminal will be moved to the opposite side of the ring to avoid adjacent transformer connections to the ring. The 500 kV bus will be extended on the south corner for the new transformer position. Three single phase transformers will be installed next to the existing transformer set with the existing spare transformer shared between the two sets. The existing 2000 A breaker used for the reactor will be used to connect the transformer set to the operating bus. The existing 115 kV reactor will be relocated in substation.
Equipment Listing Five (5) 500 kV motor operated switches 1230 ft 500 kV bus One (1) 500 kV breaker Three (3) 500/115 kV 200 MVA autotransformers One (1) 115 kV breaker (for reactor) One (1) 115 kV motor operate switch (for reactor) 600 ft of 115 kV strung bus One (1) transformer differential panel
Long Lead Material – McNeil Substation Quantity Material Description *Lead Time (weeks) 3 500/115 kV 200 MVA Autotransformer 58 5 500 kV Switches 26 1 500 kV Breakers 36 1230 ft Aluminum Bus 14 Structure Steel 20 1 115 kV Switch 20 1 115 kV Breakers 20 * Lead time as of Jan 2007
Entergy Transmission Business Page 14 of 24 EMO OASIS 1500580 Facilities Study VII. Upgrade Magnolia South to Shuler 115kV line to at least 176 MVA This recommended upgrade is contained in two line segments; Magnolia South to Calhoun Switch Station & Calhoun Switch Station to Shuler. This line is 666 MCM ASCR cable and is rated for 176 MVA (~885 amps). No line upgrades are required
1) Magnolia South Substation (885 amps) Switch B0365 is rated for 1600 A and will not be upgraded. No upgrades required at this substation
2) Shuler Substation (885 amps) Switch B0558 in Shuler Substation is rated at 600 A. This switch will be upgraded to 2000 A switches.
Scope of Work: • Install (1) 2000A MOD line disconnect switch to replace existing 600A switch B0558. • Replace jumpers etc.
Relay: • Design connection diagram for new motor operator on MOD B0558. • Revise RTU drawings, AC/DC panel drawing, and cable pull list drawing. • Order new control cables. • Revise RTU host edit sheets.
VIII. Prescott Substation (Add 30.5 MVAR Capacitor Bank) Scope of Work: • Install (1) 30.5 MVAR Cap Bank with foundation • Install (1) Circuit Switcher with foundation • Install (1) Vertical Break GOAB with structure and foundation • Install (3) CCVT with structure and foundations.
Relay Work: • Purchase and install one (1) Ungrounded Capacitor Bank control panel using the ZIV relay. • Purchase and install three (3) 115kV CCVT’s. • Purchase and install (1) 115kV, 200A Line trap pre-tuned to 155 and 200 kHz. • Purchase and install one (1) 69kV Resistive Potential Device. • Purchase and install one (1) three phase potential junction box. • Purchase and install one (1) resistive potential device junction box. • Purchase and install one split AC/DC panel. • Purchase and install 10000 ft of control cable. • RTU has enough spare points.
Entergy Transmission Business Page 15 of 24 EMO OASIS 1500580 Facilities Study 5. COSTS The ICT has reviewed and determined the required upgrade associated with the Southwestern Arkansas/Northwestern Louisiana Improvement Project (formerly Sarepta Project) is included in the 2008 ICT Base Plan. The remaining upgrades will be considered as Supplemental Upgrades. For more information on cost responsibility for Base Plan and Supplemental Upgrades, see Attachment T to Entergy’s OATT. The costs shown in the table include overheads and AFUDC, but do not include tax gross up. The estimated tax gross-up rate of 32.693% may apply to the project.
Projected Costs Description Estimated Total Cost 2008 Base Plan Supplemental Completion Upgrade Upgrade Year Sarepta Sarepta 115 kV Substation 2011 $1,696,000 $1,696,000 Upgrade Sarepta 345/115 kV New 2011 $18,906,000 $18,906,000 Substation El Dorado Relay Upgrades 2011 $802,000 $802,000 Emerson Cap Bank 2011 $720,000 $720,000 S345 to S115 T-Line 2011 $139,000 $139,000 345kv Line Cut In 2011 $159,000 $159,000 Longwood Substation (SWEPCO) By Owner By Owner Lucky Substation 36 MVAR 2011 $834,000 $834,000 Capacitor Bank Vienna Substation 28.8 MVAR 2011 $697,000 $697,000 Capacitor Bank Minden – Minden Bulk 115 kV Line 2011 $4,000,000 $4,000,000 Minden Substation 2011 $520,000 $520,000 Minden Bulk Substation (Cajun) By Owner By Owner Sarepta Project Total $28,473,000 $28,473,000
McNeil Substation 500/115 kV Upgrade 2011/2012 $17,875,000 $17,875,000 Magnolia South – Shuler 115 kV line $0 $0 Magnolia South Substation $0 $0 Shuler Substation 2008/2009 $220,000 $220,000 Prescott Substation 30.5 MVAR 2008/2009 $751,000 $751,000 Capacitor Bank Total $18,846,000 $18,846,000
Entergy Transmission Business Page 16 of 24 EMO OASIS 1500580 Facilities Study 6. SCHEDULE
Transmission Lines Weeks Magnolia South – Shuler 115 kV line No upgrades
Sarepta Project Weeks Sarepta 115 kV Substation Upgrade 26 Sarepta 345/115 kV New Substation 130 El Dorado Relay Upgrades 40 Emerson Cap Bank 52 S345 to S115 T-Line 26 345kv Line Cut In 4* Longwood Substation (SWEPCO) By Owner Lucky Substation 36 MVAR Capacitor Bank 40 Vienna Substation 28.8 MVAR Capacitor Bank 40 Minden – Minden Bulk 115 kV Line 35 Minden Substation 26 Minden Bulk Substation (Cajun) By Owner *Completed after 345/115 kV auto installation
Substations Weeks McNeil Substation 500/115 kV Upgrade 130 Shuler Substation 20 Prescott Substation 30.5 MVAR Capacitor Bank 26
Notes to Duration Schedules • All construction work requiring outages will be performed during the off-peak load season. Line outages will be discussed with the SOC/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 a possibility • Construction will occur in 2009 through 2011 • Substation construction will be completed during transmission line outages. • Transmission Line and Substation projects will begin subsequent to Definition phase Project Execution Plan • Schedule durations are high level estimates at this time. Upon project approval, a detailed schedule will be produced. • Schedule durations provide Transformer 500 kV substations to be the last one to go in service in 2011 should the definition phase be started in first quarter 2008. Equipment could be purchased during the definition phase with customer approval and the durations could be minimized. Upon project approval, a detailed schedule will be produced. • Acceleration of project can not occur due to extensive lead times.
Entergy Transmission Business Page 17 of 24 EMO OASIS 1500580 Facilities Study 7. CONFIRMED RESERVATIONS OASIS# PSE MW Begin End 140912 NRG Power Marketing 103 01/01/98 01/01/08 250778 (delisting) Entergy Services, Inc. (EMO) 1 07/02/98 07/01/11 392740 Ameren Energy Inc. 165 04/12/99 01/01/09 569011 Entergy Services, Inc. (EMO) 242 03/01/00 01/01/14 731017 South Mississippi Electric Power Assoc. 75 01/01/01 06/01/09 759196 Entergy Services (EMO) 143 01/01/01 01/01/21 759294 East Texas Electric Cooperative 31 01/01/01 01/01/18 810207 South Mississippi Electric Power Assoc. 300 01/01/02 01/01/20 810234 South Mississippi Electric Power Assoc. 300 01/01/02 01/01/20 850239 Municipal Energy Agency of Mississippi 19 05/01/01 01/01/10 850304 Municipal Energy Agency of Mississippi 13 05/01/01 06/01/10 851493 Municipal Energy Agency of Mississippi 13 05/01/01 06/01/10 1019492 South Mississippi Electric Power Assoc. 51 01/01/02 01/01/18 1024194 City Water & Light, Jonesboro 83 01/01/03 01/01/10 1024198 City Water & Light, Jonesboro 168 01/01/03 01/01/10 1035455 South Mississippi Electric Power Assoc. 280 01/01/03 01/01/08 1036858 South Mississippi Electric Power Assoc. 280 01/01/08 01/01/21 1084342 East Texas Electric Cooperative 50 01/01/05 01/01/09 1084344 East Texas Electric Cooperative 50 01/01/05 01/01/09 1084345 East Texas Electric Cooperative 75 01/01/05 01/01/09 1096986 Tennessee Valley Auth BPT 73 09/01/03 09/01/13 1099991 City Water & Light, Jonesboro 83 01/01/10 01/01/16 1099997 City Water & Light, Jonesboro 168 01/01/10 01/01/16 1105665 Entergy Services, Inc. (EMO) 185 02/01/03 02/01/16 1105666 Entergy Services, Inc. (EMO) 91 02/01/03 02/01/27 1105668 Entergy Services, Inc. (EMO) 206 02/01/03 02/01/27 1126821 Entergy Services, Inc. (EMO) 101 05/01/04 05/01/29 1139973 South Mississippi Electric Power Assoc. 95 05/01/03 12/30/28 1139975 South Mississippi Electric Power Assoc. 95 05/01/04 12/31/29 1139977 South Mississippi Electric Power Assoc. 95 05/01/05 12/31/29 1139982 South Mississippi Electric Power Assoc. 130 01/01/03 01/01/20 1151106 Entergy Services, Inc. (EMO) 20 06/01/10 06/01/29 1161925 CLECO Power LLC (Gen) 12 08/01/03 01/01/10 1161927 CLECO Power LLC (Gen) 7 08/01/03 01/01/10 1161928 CLECO Power LLC (Gen) 7 08/01/03 01/01/10 1168061 Entergy Services, Inc. (EMO) 80 08/01/04 02/01/28 1168408 Entergy Services, Inc. (EMO) 247 08/01/04 02/01/28 1192287 (1140407) Entergy Services, Inc. (EMO) 725 01/01/05 09/01/33 1202470 NRG Power Marketing 91 04/01/04 04/01/09 1286481 Merrill Lynch Commodities 11 01/01/00 01/01/10 1289686 (delisting) Entergy Services Inc. (EMO) 1 06/01/07 06/01/30 1294132 Entergy Services, Inc. (EMO) 526 01/01/06 01/01/35 1309874 East Texas Electric Cooperative 75 01/01/09 01/01/17 1309875 East Texas Electric Cooperative 50 01/01/09 01/01/17 1309876 East Texas Electric Cooperative 50 01/01/09 01/01/17 1310448 (1284799) Entergy Services Inc. (EMO) 1 06/01/07 06/01/30
Entergy Transmission Business Page 18 of 24 EMO OASIS 1500580 Facilities Study
OASIS# PSE MW Begin End (delisting) 1328125 CLECO Power Marketing 35 01/01/06 01/01/11 1340017 Plum Point Energy Associates 40 03/01/10 03/01/40 1340019 Plum Point Energy Associates 35 03/01/10 03/01/40 1340028 Plum Point Energy Associates 50 03/01/10 03/01/30 1340029 Plum Point Energy Associates 50 03/01/10 03/01/30 1340665 Entergy Services, Inc. (EMO) 200 01/01/06 01/01/09 1340673 Entergy Services, Inc. (EMO) 50 06/01/07 06/01/08 1340674 Entergy Services, Inc. (EMO) 50 06/01/08 06/01/09 1346435 Entergy Services, Inc. (EMO) 100 06/01/07 06/01/08 1346437 Entergy Services, Inc. (EMO) 100 06/01/08 06/01/09 1346440 Entergy Services, Inc. (EMO) 200 06/01/07 06/01/08 1346441 Entergy Services, Inc. (EMO) 200 06/01/08 06/01/09 1346444 Entergy Services, Inc. (EMO) 179 02/01/07 02/01/08 1348508 CLECO Power Marketing 10 01/01/06 01/01/10 1352704 (1340032) Plum Point Energy Associates 5 03/01/10 03/01/40 1356328 Municipal Energy Agency of Mississippi 40 06/01/10 06/01/40 1372645 Morgan Stanley Commodities Group 102 01/01/07 01/01/08 1372646 Morgan Stanley Commodities Group 102 01/01/07 01/01/08 1373643 City of Conway 25 03/01/10 03/01/40 1373714 East Texas Electric Cooperative 63 01/01/10 01/01/30 1375299 Louisiana Generating LLC 11 03/01/06 03/01/11 1375300 Louisiana Generating LLC 8 03/01/06 03/01/11 1375301 Louisiana Generating LLC 5 03/01/06 03/01/11 1375559 CLECO Power LLC 675 12/01/06 12/01/16 1380484 Osceola Light & Power 9 09/01/09 09/01/39 1381068 Plum Point Energy Associates 100 06/01/10 06/01/11 1381398 Constellation Energy Group 34 01/01/06 01/01/36 1381400 Constellation Energy Group 34 01/01/06 01/01/36 1381404 Constellation Energy Group 17 01/01/06 01/01/36 1381406 (1325187) Constellation Energy Group 17 01/01/06 01/01/36 1383852 AECC 550 01/01/07 01/01/17 1385835 (1363730) City of Prescott 22 04/01/06 04/01/09 1385842 South Mississippi Electric Power Assoc. 100 01/01/09 01/01/10 38 01/01/10 01/01/11 1387272 CLECO Power 11 04/01/06 04/01/16 1389008 NRG Power Marketing 270 06/01/07 06/01/08 1389848 Louisiana Energy & Power Authority 6 02/01/07 02/01/08 1401985 Constellation Commodities Group 42 08/01/06 08/01/36 1403756 Constellation Commodities Group 100 01/01/07 01/01/08 1403757 Constellation Commodities Group 100 01/01/07 01/01/08 1406786 South Mississippi Electric Power Assoc. 100 04/01/10 04/01/40 1407894 Morgan Stanley Commodities Group 102 01/01/08 01/01/09 1407895 Morgan Stanley Commodities Group 102 01/01/08 01/01/09 1408199 South Mississippi Electric Power Assoc. 100 04/01/10 04/01/40 1408981 NRG 92 01/01/07 01/01/10 1410022 (1340037) City of North Little Rock 60 03/01/10 03/01/40
Entergy Transmission Business Page 19 of 24 EMO OASIS 1500580 Facilities Study
OASIS# PSE MW Begin End 1412068 NRG 103 01/01/07 01/01/08 1413110 NRG Power Marketing 100 01/01/07 01/01/09 1414925 Constellation Commodities Group 22 01/01/07 01/01/08 1414927 Constellation Commodities Group 50 01/01/07 01/01/08 1416650 NRG Power Marketing 100 01/01/07 01/01/08 1422496 Constellation Commodities Group 57 01/01/07 01/01/08 1422498 Constellation Commodities Group 9 01/01/07 01/01/08 1425495 East Texas Electric Cooperative 50 03/01/10 03/01/45 1431621 South Mississippi Electric Power Assn. 200 01/01/07 01/01/08 1443976 (1424383) Constellation Commodities Group 9 01/01/07 01/01/08 1435972 Entergy Services, Inc. (EMO) 150 05/01/07 05/01/10 1435973 Entergy Services, Inc. (EMO) 135 05/01/08 05/01/10 1436590 MidAmerican Energy 50 01/01/07 01/01/08 1436591 MidAmerican Energy 50 01/01/07 01/01/08 1436592 MidAmerican Energy 50 01/01/07 01/01/08 1436593 MidAmerican Energy 50 01/01/07 01/01/08 1440358 NRG Power Marketing 100 03/01/07 03/01/08 1442295 NRG Power Marketing 3 07/01/07 07/01/09 1442453 NRG Power Marketing 320 06/01/07 06/01/26 1448054 NRG Power Marketing 103 01/01/08 01/01/09 1448057 NRG Power Marketing 103 01/01/08 01/01/09 1449494 Entergy Services, Inc. (EMO) 154 06/01/07 06/01/09 1449495 Entergy Services, Inc. (EMO) 322 06/01/09 06/01/59 1449881 Cargill Power 103 01/01/08 01/01/09 1452308 NRG Power Marketing 100 01/01/08 01/01/09 1452603 NRG Power Marketing 100 09/01/07 09/01/08 1435303 East Texas Electric Coop 150 01/01/07 01/01/40 1453402 NRG Power Marketing 103 01/01/09 01/01/10 1456636 CLECO Power LLC 10 10/01/07 10/01/12 1458787 Louisiana Energy & Power Authority 2 03/31/07 03/31/08 1464028 East Texas Electric Coop 168 01/01/10 01/01/40 1466197 NRG Power Marketing 206 01/01/09 01/01/10 1466561 Constellation Energy 50 01/01/08 01/01/09 1466562 Constellation Energy 25 01/01/08 01/01/09 1470811 East Texas Electric Coop 186 01/01/10 01/01/40 1477069 Entergy Services 10 11/01/07 11/01/37 1477256 NRG Power Marketing 103 01/01/08 01/01/09 1479051 Ameren Energy Mktg 103 07/01/08 07/01/09 1485805 NRG Power Marketing 103 07/01/08 07/01/09 1494443 Constellation Energy 35 01/01/08 01/01/09 1494445 Constellation Energy 75 01/01/08 01/01/09 1494446 Constellation Energy 75 01/01/08 01/01/09 1494450 Constellation Energy 25 01/01/08 01/01/09
Entergy Transmission Business Page 20 of 24 EMO OASIS 1500580 Facilities Study Pre-888 Transactions
OASIS # PSE MW Begin End 1219160 NRG Power Marketing 91 4/1/2009 4/1/2014 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
Entergy Transmission Business Page 21 of 24 EMO OASIS 1500580 Facilities Study 8. STUDY QUEUE
OASIS PSE MW Begin End 1338849 Louisiana Energy & Power Authority 45 9/1/2005 9/1/2010 1413255 American Electric Power Service Corp 225 01/01/07 01/01/09 1460876 Aquila Networks – MPS 75 03/01/09 03/01/29 1460878 Aquila Networks – MPS 75 03/01/09 03/01/29 1460879 Aquila Networks – MPS 75 03/01/09 03/01/29 1460881 Aquila Networks – MPS 75 03/01/09 03/01/29 1460900 Louisiana Energy & Power Auth 116 01/01/09 01/01/30 1468113 Muni energy Agcy of Miss 20 06/01/11 06/01/41 1468285 Mid American Energy 103 09/01/07 09/01/08 1468286 Mid American Energy 103 09/01/07 09/01/08 1468288 Mid American Energy 103 01/01/08 01/01/09 1468289 Mid American Energy 103 01/01/08 01/01/09 1470484 City of W. Memphis 20 01/01/11 01/01/41 1471303 Cargill Power Markets, LLC 103 01/01/08 01/01/09 1475343 Constellation Energy 25 01/01/08 01/01/09 1477636 Westar Energy Generation & Mktg 27 06/01/10 06/01/40 1477639 Westar Energy Generation & Mktg 15 06/01/10 06/01/11 1478781 Entergy Services 804 01/01/08 01/01/58 1481059 Constellation Energy 60 02/01/11 02/01/30 1481111 City of Conway 50 02/01/11 02/01/46 1481119 Constellation Energy 30 02/01/11 02/01/30 1481235 Louisiana Energy and Power Authority 50 02/01/11 02/01/16 1481438 NRG Power Marketing 20 02/01/11 02/01/21 1483241 NRG Power Marketing 103 01/01/10 01/01/20 1483243 NRG Power Marketing 206 01/01/10 01/01/20 1483244 NRG Power Marketing 309 01/01/10 01/01/20 1483247 NRG Power Marketing 515 01/01/10 01/01/20 1483485 Entergy Services (EMO) 100 01/01/08 01/01/11 1483490 Entergy Services (EMO) 1 01/01/08 01/01/11 1487880 NRG Power Marketing 300 01/01/08 01/01/10 1495910 Southwestern Electric Cooperative 78 05/01/10 05/01/13 1498120 Constellation Energy 60 04/01/12 04/01/42 1498122 Constellation Energy 30 04/01/12 04/01/42
Entergy Transmission Business Page 22 of 24 EMO OASIS 1500580 Facilities Study
OASIS PSE MW Begin End 1498129 Conway Corporation 50 04/01/12 04/01/42 1498226 Carthage Water & Electric 4 04/01/12 04/01/42 1499610 NRG Power Marketing 300 01/01/08 01/01/13
Entergy Transmission Business Page 23 of 24 EMO OASIS 1500580 Facilities Study 9. ATTACHMENTS 1) Location Drawings
Description Page Over-all Locations A-1 Sarepta Area A-2 McNeil – Shuler Area A-3
2) One Line Drawings
Description Page Emerson Substation A3651SO5 Lucky Substation L0410SO5 McNeil Substation (existing substation) A2015SO1 McNeil Substation (Concept Sketch) McNeil New Auto Magnolia Substation A3721SO1 Minden Substation L0422SO1 Prescott Substation A3759SO5 Shuler Substation A3768SO1 Sarepta Substation (existing substation) L0452SO1 Vienna Substation L0413SO5
3) Sarepta Project Execution Plan
Entergy Transmission Business Page 24 of 24
C:\Documents and Settings\dcummi1\Desktop\Oasis\Emerson\A3651SO5.DWG, 1/16/2008 8:56:28 AM, dcummi1 FOR CONSTRUCTION
C:\Documents and Settings\dcummi1\Desktop\Oasis\Minden\L0422SO1.DWG, 1/18/2008 3:04:35 PM, dcummi1 C:\Documents and Settings\dcummi1\Desktop\Oasis\Prescott\A3759SO5.dwg, 1/16/2008 9:17:26 AM, dcummi1 PRELIMINARY C:\Documents and Settings\dcummi1\Desktop\Oasis\Shuler\A3768SO1.DWG, 1/16/2008 11:20:54 AM, dcummi1
Revision e
TRANSMISSION SUBSTATION PROJECTS
COMPANY: ENTERGY TRANSMISSION
CUSTOMER: ELI/EAI BI NUMBER: F1PPU50408
PROJECT EXECUTION PLAN
FOR
SAREPTA: BUILD 345/115KV SUBSTATION
Revision: e
PROGRAM MANAGER Charles Newell
Revised Project Rev Rev Date Description of Revision By Manager
a 3/6/06 Initial draft M. Mullins M. Mullins
e 9/13/06 JET Review M. Mullins M. Mullins
Rev 0 M. Mullins M. Mullins
Revision e
TABLE OF CONTENTS Project Execution Plan (P.E.P.) TABLE OF CONTENTS...... 2
1 INTRODUCTION: ...... 5
2 EXECUTIVE SUMMARY: ...... 5
3 GENERAL PROJECT DESCRIPTION (KEY PROJECT DATA): ...... 6 3.1 PROJECT DESIGN AND CONSTRUCTION REQUEST (PDCR) ...... 6 3.2 PROJECT SCOPING PLAN (PSP)...... 6 3.3 DESCRIPTION OF THE PROJECT: SEE EXECUTIVE SUMMARY...... 6 3.4 PURPOSE/GOALS OF THE PROJECT: SEE EXECUTIVE SUMMARY ...... 6 3.5 PROJECT ALTERNATIVES AND PROPOSED METHODOLOGY...... 6 3.6 TYPE OF PROJECT AND JUSTIFICATION: ...... 6 3.7 IN SERVICE DATES: ...... 6 3.8 PRELIMINARY ESTIMATE OF COSTS:...... 6 3.9 MAJOR GOVERNING POLICIES: N/A...... 6 3.10 CRITICAL SUCCESS FACTORS: ...... 6 3.11 N/A ...... 6 3.12 N/A ...... 6 4 PROJECT STRATEGIC PLANNING – KEY EXECUTION STRATEGIES ...... 7 4.1 ASSUMPTIONS & THEIR POTENTIAL EFFECTS...... 7 4.1.1 Budget Approval Date: ...... 7 4.1.2 Outage Assumptions: ...... 7 4.1.3 Environmental Assumptions...... 7 4.1.4 Adjacent Substation Impacts...... 7 4.2 CONSTRAINTS & RESULTS...... 8 4.3 PERMIT REQUIREMENTS ...... 8 4.4 ELI REGULATORY ...... 8 4.5 RISK PLANNING ...... 8 4.6 FUNDING ...... 8 4.7 CONTRACTING STRATEGY ...... 8 4.8 MATERIAL PROCUREMENT STRATEGY ...... 8 4.9 TECHNOLOGY STRATEGY ...... 9 4.10 RELATIVE PRIORITIES...... 9 5 SAFETY AWARENESS AND EXECUTION PLAN:...... 9
6 SCOPE:...... 9 6.1 DETAILED SCOPE SUMMARY ...... 9 6.2 WORK BREAK DOWN STRUCTURE (N/A) ...... 9 6.3 SCOPE DETAILS ...... 9 6.3.1 Generic Scope Details...... 9 6.3.2 El Dorado Substation Improvements (EAI) ...... 10 6.3.2.1 Foundation Work ...... 10 6.3.2.2 Electrical Work...... 10 6.3.2.3 Relay Work...... 10 6.3.2.4 Settings / RTU Configurations Work...... 12 6.3.2.5 Metering Upgrade...... 12 6.3.3 Emerson (EAI) Capacitor Bank ...... 12 6.3.3.1 Site Work...... 13
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6.3.3.2 Foundation Work ...... 13 6.3.3.3 Electrical Work...... 14 6.3.3.4 Relay / Configurations Work ...... 14 6.3.3.5 Relay Settings / RTU Configuration Work ...... 15 6.3.4 Longwood Substation Improvements ...... 15 6.3.5 345kv Transmission Line Cut In ...... 15 6.3.5.1 Existing Line Data and Required Material for Cut-In...... 15 6.3.5.2 Assumptions for Transmission Line ...... 16 6.3.5.3 T-line construction...... 16 6.3.6 Sarepta 345kv to Sarepta 115kv T-Line...... 16 6.3.6.1 Line design...... 16 6.3.6.3 T-line construction...... 16 6.3.7 Sarepta 345kV Substation ...... 16 6.3.7.1 Site Work...... 17 6.3.7.2 Foundations...... 17 6.3.7.3 Electrical Work...... 18 6.3.7.4 Relay/Settings/Configuration Work...... 19 6.3.7.5 Communications ...... 22 6.3.7.6 Metering...... 22 6.3.7.7 SCADA...... 22 6.3.8 Sarepta 115kV Substation ...... 23 6.3.8.1 Site Work...... 23 6.3.8.2 Foundations...... 23 6.3.8.3 Electrical Scope ...... 23 6.3.8.4 Relay Scope ...... 24 6.4 SOC NOTIFICATIONS/MODIFICATIONS ...... 24 6.5 DRAWING INDEX...... 24 7 PROJECT ORGANIZATION...... 24
8 MATERIALS MANAGEMENT PLAN ...... 25 8.1 STRATEGY ...... 25 8.2 LONG LEAD TIME MAJOR EQUIPMENT ...... 25 Material Description ...... 25 8.3 BULK MATERIALS – N/A...... 26 8.4 STOREROOM MATERIALS – BOM’S...... 26 8.5 VENDORS – STANDARD VENDORS FOR SUBSTATION EQUIPMENT ...... 26 8.6 USE OF SYSTEM SPARES – N/A...... 26 8.7 USE OF TEMPORARY EQUIPMENT – N/A...... 26 8.8 SALVAGED EQUIPMENT – N/A ...... 26 8.9 USE OF SYSTEM SPARES – N/A...... 26 8.10 MONETARY AND REPORTING – N/A ...... 26 8.11 RECEIPT PROCEDURES – N/A...... 26 8.12 SPECIAL CONSIDERATIONS – N/A...... 26 9 RESOURCE PLAN ...... 26 9.1 CONTRACTING STRATEGY ...... 26 9.2 RFQ – TO BE HANDLED BY CONSTRUCTION...... 27 9.3 BID RECEIPT – TO BE HANDLED IAW ENTERGY COMMERCIAL BUSINESS POLICIES ...... 27 9.4 COMMERCIAL BID - TO BE HANDLED IAW ENTERGY COMMERCIAL BUSINESS POLICIES ...... 27 9.5 TECHNICAL BID - TO BE HANDLED IAW ENTERGY COMMERCIAL BUSINESS POLICIES...... 27 9.6 TYPICAL PROJECT EXECUTION BID – N/A ...... 27 9.7 BID SUBMISSION - TO BE HANDLED IAW ENTERGY COMMERCIAL BUSINESS POLICIES ...... 27 9.8 BID REVIEW OBJECTIVES - TO BE HANDLED IAW ENTERGY COMMERCIAL BUSINESS POLICIES ...... 27 9.9 ALIGNMENT WITH OVERALL PROJECT – N/A ...... 27 9.10 CONTRACT ADMINISTRATION – CONTRACTS WILL BE ADMINISTERED BY CONSTRUCTION...... 27
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10 PROJECT CONTROLS PLAN...... 27 10.1 PROJECT WORK ORDERS ...... 27 10.2 COST MANAGEMENT PLAN...... 27 10.2.1 Baseline Estimates ...... 27 10.2.2 El Dorado Substation TS9376...... 27 10.2.3 Emerson 115kV Substation (EAI) TS9375 ...... 27 10.2.4 Eldorado to Longwood Transmission Line Cut In TL4xxx ...... 27 10.2.5 Sarepta 345kV to Sarepta 115kv T-Line ...... 27 10.2.6 Sarepta 345kV Substation TS9370...... 28 10.2.7 Sarepta 115kV Substation TS9377...... 28 10.3 TIME MANAGEMENT PLAN (SCHEDULING)...... 28 10.4 CHANGE MANAGEMENT PLAN...... 28 10.5 PROJECT REPORTS ...... 28 10.6 MILESTONES...... 28 10.7 GATE REVIEWS...... 28 11 QUALITY ASSURANCE PLAN...... 28
12 CONSTRUCTION MANAGEMENT PLAN...... 28 12.1 SITE CONSTRUCTION STRATEGY ...... 28 12.2 ORGANIZATION – N/A ...... 29 12.3 CONSTRUCTION STANDARDS...... 29 12.4 PROJECT EXECUTION ...... 29 12.5 SAFETY – SPECIAL CONSIDERATIONS...... 29 13 RISK MANAGEMENT PLAN...... 29 13.1 RISK IDENTIFICATION ...... 29 14 REGULATORY & ENVIRONMENTAL COMPLIANCE PLAN(S) ...... 29
15 START UP AND TURNOVER PLANS ...... 30
16 PROJECT CLOSURE ...... 30 16.1 SCOPE VERIFICATION ...... 30 16.2 PROJECT CRITIQUE – N/A...... 30 16.3 LESSONS LEARNED...... 30 16.4 PROJECT CLOSEOUT PROCESS ...... 30 17 ADMINISTRATIVE PLANS (S)...... 30
18 COMMUNICATIONS PLAN...... 31 18.1 RECORD OF CRITICAL COMMUNICATIONS ...... 32 19 LIST OF ATTACHMENTS TO THE PROJECT EXECUTION PLAN...... 33
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1 INTRODUCTION:
The 115kV line from McNeil to Emerson in South Arkansas is 56 miles long. The loss of any section of the line between McNeil to Emerson will cause severe low voltages (68% to 91% to 6 stations). 94MW are at risk in 20061. The objective of this project is to construct a new 345/115kV substation at Sarepta to relieve low voltages caused by single contingencies. Also, a 21.6MVAR capacitor bank will be installed at Emerson and relay modifications will be made at Longwood (SWEPCO) and at El Dorado as part of this project. This project will benefit the system by alleviating the anticipated violation of NERC Planning Standard I.A.S2.M2 performance criteria associated with Category 'B' contingencies.
2 EXECUTIVE SUMMARY:
Targeted ISD June 2008 Projected ISD ?
A number of options have been considered to solve the issued defined above. Transmission Planning has selected the solution to be installing an auto transformer at Sarepta Substation to connect the 345kv line near the substation to the existing 115kv substation. Entergy owns a considerable amount of property around the Sarepta Substation therefore no additional property acquisitions will be necessary.
El Dorado Substation 500/345/115 (EAI): (345kv Line North end point) Relaying will need to be upgraded.
Emerson (EAI): a 21.6 MVAR fuseless capacitor bank will be installed at Emerson Substation in EAI. The configuration will be [manual switch][circuit switcher][Capacitor bank]. One 400 amp trap will be required on the A Phase.
Longwood Substation (SWEPCO): (345kv Line south end point) Relaying will need to be examined and upgraded. These activities will be coordinated through Entergy’s wholesale account representative assigned to SWEPCO.
Transmission line construction will be entirely on existing property owned by Entergy therefore no ROW acquisitions or CCN activities will be required.
Sarepta 345kv Substation: The general scope of the project will be to construct a ring bus on the property adjacent to the existing 345kV dead end towers. The 345kv lines will be cut in to the substation. A 115kv connect the old and new substation effectively becoming a new source line into the Sarepta 115kv Substation. For all practical purposes, the new substation will be a completely stand alone facility attached via control cables and ground grid only to the existing substation.
Transformer: 345kv/115kv 300MVA, 3 phase, buried tertiary, No Load Tap Changer (# Steps 5), Impedance = 12%.
115kv Sarepta Substation: There will be considerable upgrades required for this substation. It will include: Replacing two switches on R6455, installing 3 CVT’s, two circuit switchers, and upgrading the battery.
1 Per email from E. Habibovic 9/12/06
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3 GENERAL PROJECT DESCRIPTION (KEY PROJECT DATA):
3.1 Project Design and Construction Request (PDCR)
Filed in E-room.
3.2 Project Scoping Plan (PSP)
Filed in E-room.
3.3 Description of the Project: See Executive Summary
3.4 Purpose/goals of the Project: See Executive Summary
3.5 Project Alternatives and Proposed Methodology
This project is an alternative solution to a transmission planning problem defined above.
3.6 Type of Project and Justification:
Transmission Reliability (M)
3.7 In Service Dates:
Overall project requested: 6/1/08
El Dorado – Projected: 7/1/08 Emerson - Projected: 12/1/08 SWEPCO/AEP – Projected: 7/1/08 345kv Line cut in – Projected: 7/1/08 Sarepta 345 to Sarepta 115 line – Projected: 8/1/08 Sarepta 345kv – Projected: 9/1/08 Sarepta 115kv – Projected: 12/31/07
Milestones: See schedule
The work will be scheduled to optimize resources, available funds and outages.
3.8 Preliminary Estimate of Costs: See attached EXCEL Estimate Summary
3.9 Major Governing Policies: N/A
3.10 Critical Success Factors:
Critical Success will be defined as having the station in service before it is needed.
3.11 N/A
3.12 N/A
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4 PROJECT STRATEGIC PLANNING – KEY EXECUTION STRATEGIES
4.1 Assumptions & Their Potential Effects
4.1.1 Budget Approval Date:
Scoping must be performed in 2006 to achieve the needed ISD. Funding for 2006 has been approved. Funding for 2007 must be approved by end of 2006 to allow work to begin.
4.1.2 Outage Assumptions:
The El Dorado to Longwood (SWEPCO) 345kV transmission line can be de-energized for the duration needed to complete the slack span cut-in and to complete relay modifications at El Dorado and at Longwood (SWEPCO). No more than 3 days are anticipated for this outage.
The 115kV operating bus at Sarepta can be de-energized for the duration needed to complete the necessary modifications. The transformers can be placed on the inspection bus, the capacitor bank cannot.
13.8kv Transformer in Sarepta 115kv Substation: Outage to install the circuit switcher can be scheduled any time of the year.
34.5kv Transformer in Sarepta 115kv Substation: Outage to install circuit switcher can not be scheduled during the summer. There is a load sensitive industrial customer on this transformer, so outages must be coordinated through the major account representative, Jeff Aycock.
An appropriate outage on the lines in and out of Emerson can arranged to place the capacitor bank in service. The land currently owned by Entergy at the Emerson site is sufficient to allow moving the fence out and installing the new capacitor bank.
4.1.3 Environmental Assumptions
An environmental assessment will be performed on both the new site to determine if any adverse conditions exist. None are expected on the line route.
Sarepta 345kv will be a limestone surfacing. Sarepta 115kv will not be covered in limestone as a project necessary portion of this project. Emerson 115kv has a cover of limestone and washed gravel. The new yard section will be covered in washed gravel.
4.1.4 Adjacent Substation Impacts
This project will create a new breaker point in between El Dorado and Longwood.
El Dorado 500/345/115 Substation (EAI) – Relay upgrades will be required. The line traps will have to be replaced/retuned to accommodate the new node at Sarepta 345kV. A new frequency will be used on the El Dorado – Sarepta Line.
Longwood (SWEPCO) – Relay upgrades will be required. The line traps will not have to be replaced/retuned to accommodate the new node at Sarepta 345kV because the existing frequency will become the Sarepta to Longwood Frequency.
The Sarepta 345 to Longwood 345 relaying configuration will be as follows:
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The existing line relay frequency will be used between Sarepta and Longwood. Primary = SEL 421 at Sarepta and SEL 421 at Longwood, blocking scheme Secondary = SEL 421 at Sarepta and GED60 at Longwood, unblocking scheme Dual Direct Transfer Tripping (Sarepta and Longwood) Digital Fault Recorder Required Carrier will be RFL from Pulzar Universal Power Line Carrier from Sarepta to Longwood
4.2 Constraints & Results
Management approval of an appropriate stream of funding for this project will hold up progress.
4.3 Permit Requirements None
4.4 ELI Regulatory
There may be some interaction at a FERC level due to the interaction between two utilities. These matters will be handled via the Transmission Policy and Account.
4.5 Risk Planning
See Section 13
4.6 Funding
The budget for the first year of the project, will be to scope the project. Funding in 2007 will be for site and foundation work on the new substation and upgrade work on all existing facilities. Funding in 2008 will be for steel erection and final assembly of the new substation. The largest single purchases will be the breakers and transformer which will be purchased near the end of the project to minimize the time the financial resources are expended but not in service. A detailed funding schedule will be provided in this document.
The funding strategy for this project is as follows: Develop a Funding Project to encompass the following tasks:
Scope and begin design Sarepta 345kv Project 2006 Upgrade Sarepta 115kv, Longwood and Eldorado Substations 2007 Perform site work and start foundations on Saretpa 345kv – 2007 Install Emerson Cap Bank during fall 2008 Complete Sarepta 345kv substation – 2008
See attached EXCEL Estimate Summary
4.7 Contracting Strategy
External contractors will be used for T-Line, site, foundation and electrical work. Internal resources will be used for all other services.
4.8 Material Procurement Strategy
No surplus material will be used. All material will be purchased new.
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4.9 Technology Strategy
N/A.
4.10 Relative Priorities
5 SAFETY AWARENESS AND EXECUTION PLAN:
Sarepta 345kv is a new green field site so there are no existing energized equipment concerns, however work will be done near an energized 345kV, 115kV, 34.5kv and 13.8kv lines. Normal construction safety preformed in accordance with “Transmission and Distribution Safety Manual” will address the safety issues.
Sarepta 345kv Substation will require an unusually large transformer by normal Entergy standards. This will require a qualified heavy lift contractor. Offloading, staging and placing the transformer will require extra attention.
Sarepta 115kv Substation will involve a number of complex switching outages to preserve service to customers and provide a sufficient outage envelope to allow the relaying upgrades. The design sequence should accommodate these outages.
Longwood, Emerson and Eldorado are energized and work in the station will need be coordinated with appropriate outages.
Sarepta will involve cutting into an existing 345kV transmission line. Appropriate EHV safety precautions will be required.
6 SCOPE:
6.1 Detailed Scope Summary
See executive summary.
6.2 Work Break Down Structure (N/A)
6.3 Scope Details
6.3.1 Generic Scope Details El Dorado control voltage: 132vdc Emerson 115kv control voltage: 48vdc and 125vdc Transmission Line voltages will be 345kVand 115kv Sarepta 345kv control voltage: 125vdc Sarepta 115kv control voltage: 125vdc El Dorado Substation Asset Location Number: 2002 Emerson Asset Location Number: 3651 El Dorado to Longwood T-Line Asset Location Number: ______Sarepta 345kv Substation Asset Location Number: 0475 Sarepta 115kv Substation Asset Location Number: 0452 Sarepta 345kv to Sarepta 115kv Asset Location Number: 0300
General Relay Philosophy
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Sarepta 345 to Longwood
• Primary = SEL 421 at Sarepta and SEL 421 at Longwood, blocking scheme • Secondary = SEL 421 at Sarepta and DCB at Longwood, unblocking scheme
El Dorado to Sarepta
• Primary 1= SEL 421 at Sarepta and SEL 421 at El Dorado, unblocking scheme • Primary 2= SEL 421 at Sarepta and SEL 421 at El Dorado, Unblocking scheme • Backup = L-Pro at El Dorado
• Digital Fault Recorder Required
• Dual Direct Transfer Tripping (Sarepta and El Dorado) • Dual Direct Transfer Tripping (Sarepta and Longwood)
• Carrier will be RFL from Sarepta to El Dorado and Pulzar UPLC from Sarepta to Longwood
6.3.2 El Dorado Substation Improvements (EAI)
6.3.2.1 Foundation Work
• The relay design calls for new slip over CT’s on the 500 to 345 auto transformer. Conduit will be needed to support these CT’s.
• Three CCVT’s will be installed in place of the A and C phase coupling capacitors. This will require additional foundations and conduit.
6.3.2.2 Electrical Work
• Install conduit and equipment for the CT’s.
6.3.2.3 Relay Work
• There are two separate control houses connected by a short enclosed hallway at El Dorado EHV Substation. The existing Longwood relaying equipment and GE Harris RTU main unit are located in the older control house. All work for this project will be done in the old building.
• Remove all GE Primary Static Relaying and CS-26A carrier set from the Longwood Primary Relaying Cabinet 17C.
• Remove GE CT-51 / CR-51 Transfer Trip equipment from the Longwood Transfer Trip Cabinet 18C.
• Remove all Telemetry equipment from Cabinet 19C.
• Retrofit Longwood Primary Relaying Cabinet 17C with a Schweitzer Engineering Laboratories SEL-421 for line protection, RFL 9780 three frequency unblocking carrier set, and all other necessary auxiliary equipment need for testing and maintenance (carrier cutoff switch, direct transfer trip test switch, etc.). This cabinet will coordinate with the Primary 1 Line Relaying Panel to be installed at the new Sarepta Substation. New Transfer trip and
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unblocking frequencies will be specified by the Entergy Relay Settings Group for the Sarepta to El Dorado Line. Re-label the cabinet as “Sarepta Primary 1 Relay Cabinet”. Reference retrofit done at Keo Substation for the ISES line primary relaying asset no. A2009. (A2009LO5)
• Retrofit the existing Longwood Transfer Trip Cabinet 18C with a Schweitzer Engineering Laboratories SEL-421 for line protection, RFL 9780 three frequency unblocking carrier set, transfer trip unit and all other necessary auxiliary equipment needed for testing and maintenance (carrier cutoff switch, direct transfer trip test switch, etc.). This cabinet will coordinate with the Primary 2 Line Relaying Panel installed at the new Sarepta Substation. Transfer trip and unblocking frequencies will be specified by the Entergy Relay Settings Group for the Sarepta to El Dorado Line. Re-label the cabinet as “Sarepta Primary 2 Relay Cabinet”. Reference retrofit done at Keo Substation for the ISES line primary relaying asset no. A2009. (A2009LO5)
• Retrofit the existing Telemetry Cabinet 19C with a NxtPhase L-Pro relay and all other necessary auxiliary equipment needed for testing and maintenance. This relay will be used as backup protection against common mode failure of the SEL-421 relays.
• There is currently only one set of CTs in the low side transformer bushings being used for line protection. In order to achieve full redundant protection an additional set will be needed. Purchase and install four 2000:5 slip over CTs. These will be installed on the low side bushings of the 500/345kV autotransformer. To provide the best overlap in protection these new CTs will be for as the transformer protection relays and the CTs currently being used for transformer protection will be used for the Primary 2 line relaying. Each CT slip over CT shall be wired to the existing Autotransformer Junction Box.
• No new AC circuits will be needed to perform this project.
• The existing DC panel has four spare 100A and two spare 40A circuit breakers. This will be adequate to complete the project.
• The existing line traps line traps on the Longwood 345kV Line are over thirty years old and can not easily be retuned. To ensure proper carrier communication purchase and install two 345kV, 2000A Single Frequency Line Traps. Reference Entergy Purchase Standard PM0802, latest revision. These units shall be ordered factory tuned to the new frequencies specified by the Entergy relay settings group.
• Purchase and install two Single Frequency Line Tuners. Reference Entergy Purchase Standard PM0804, latest revision. These tuners will replace the existing line tuners on the Longwood 345kV Line. These units shall be ordered factory tuned to the new frequencies specified by the Entergy relay settings group.
• The existing coupling capacitors and line potential transformers are over thirty years old purchase and install a total of five 345kV CCVTs. All CCVTs are to be metering accuracy and shall have carrier accessories installed for ease of construction coordination as well as future use. Reference Entergy Purchase Standard PN0201, latest revision.
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• Two CCVTs will replace the existing A-phase and C-phase coupling capacitors on the existing Longwood 345kV Line. The single phase junction boxes for these CCVTs will also be replaced. Purchase, design, and install two Single Phase CVT Junction Boxes. Reference Entergy Design Standard PM2402, latest revision.
• Three CCVTs will replace the existing PTs on the existing Longwood 345kV Line Node. The bus potential junction box for these CCVTs will also be replaced. Purchase, design, and install one Bus Potential Junction Box. Reference Entergy Design Standard PM2402, latest revision.
• The existing GE Harris RTU main unit is located in the old control house, and peripheral cards are located in the new control house. There are not enough spare points in the main unit to accommodate this new installation. There is also no more room in the RTU cabinet to install and additional card. Purchase and install one RTU expansion cabinet consisting of two D20-S cards with DB25 connectors and wiedmuller terminal blocks. This unit will be installed next to the existing main RTU cabinet.
• There is an existing SEL-2020 and Teltone located in the new control house. Because of its processing limitations the SEL-2020 will not be adequate for the addition of the 2 new SEL-421 relays. Purchase, design and install one Orion 5r Communications / Port Switcher. The communications processor will need to be connected to the RTU to pass DNP analog data to the TOC. Entergy Asset Preservation has already brought Ethernet into the control house the Orion 5r should be connected to the existing router. Because of the long distance to the communications processor fiber optics will have to be used. Install SEL-2810 RS-232 fiber converters and Fiber Optic cable to connect the two SEL-421s and the L-Pro to the communications processor.
• AEP / SWEPCO currently has a data line connected to the RTU at El Dorado this will no longer be needed. Remove this data circuit.
6.3.2.4 Settings / RTU Configurations Work
• Relay settings will be required for the 2 new SEL-421 relays and the new L-Pro relay.
• A new RTU configuration will be required.
6.3.2.5 Metering Upgrade
• The metering at El Dorado EHV will remain as intra company tie metering (EAI- ELI). The metering will be upgraded to a JEMStar bi-directional meter with DNP. Purchase, design and install one JEMStar meter Catalog Number JS-09J2- 6020-51-DNP-TOT-12CH and all necessary converters and surge suppression equipment needed to connect the RS-485 DNP output from the meter to the RTU. The surge suppression equipment shall be a B&B Electronics model 4850P RS-485 Optical Isolator along with a B&B Electronics model 4850T9L RS-232 to RS-485 Optically Isolated Converter.
6.3.3 Emerson (EAI) Capacitor Bank
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A 21.6 MVAR capacitor bank (fuseless, ungrounded wye) will be installed at Emersion Substation in EAI. The capacitor bank will be installed on the Sarepta/Hayesville line side of breaker B06342. Emerson currently has two batteries, a 125vdc and a 48vdc battery. The RTU will be moved from the 48vdc to the 125vdc. At the completion of the project, if the 48vdc battery has no remaining load, it should be removed.
6.3.3.1 Site Work
• Soil borings will be required.
• The capacitor bank will be situated on the SE corner of the substation. The existing east fence will have to be relocated to the east. This will require removal of approximately 165 feet of fence and the subsequent addition of approximately 365 feet of fence.
• The ground grid will be enlarged to accommodate the station expansion.
• A topographical survey will be required for station expansion.
• There is a drainage ditch along the east fence that may need to be relocated to the east.
6.3.3.2 Foundation Work
• Install two “CE” tower drilled-pier foundations (for circuit switcher and disconnect switch).
• Install one 21.6MVAR capacitor bank drilled-pier foundation.
• Install six lally (bus support) column drilled-pier foundations.
• Install three CVT pedestal drilled-pier foundations.
• Install perimeter ground around fence (725’ of 4/o copper conductor).
• Install 200 feet of 4/o copper conductor to connect new construction to existing ground grid as per Entergy grounding standard.
• Install 1,500 feet of conduit including: - Install 1 pull box (verify with Relay Design and AP). - Install one 2” SCH 40 PVC conduit from the light to the pull box. - Install three 2” SCH 40 PVC conduits, one from each CVT to the pull box. - Install four 2” SCH 40 PVC conduits from the Mark V to the pull box. - Install two 2” SCH 40 PVC conduits from the cap bank control panel to the pull box. - Install two 2” SCH 40 PVC conduits from resistive potential device to the pull box.
• Install one light to illuminate cap bank.
2 Per email from Edin Habobivic 6/5/06
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6.3.3.3 Electrical Work
• Install one 21.6MVAR capacitor bank, fuseless, 115kV, ungrounded wye with one line trap on A phase. Provide racks for possible future expansion to 32MVAR.
• Install two “CE” towers 16 ft.
• Install one 115kV, 2000A, 125VDC, circuit switcher with enhanced pre- insertion inductors and ground blade attachments. NOTE: This assumes that the enhanced pre-insertion inductors are necessary which is dependent on verification from Transmission System Planning. The omission of enhanced pre-insertion inductors would have a cost saving effect on the estimate.
• Install one 2000A center side break gang operated air break switch between the circuit switcher and operating bus.
• Install six lally (bus support) columns.
• Install 3 CVT pedestals (E towers) **Double check with AP upon location of CVTs.
• Install fifteen 115kV station post insulators.
• Install 175 ft. 2 ½ inch rigid aluminum bus.
6.3.3.4 Relay / Configurations Work
• An operational online does not currently exist for this station and will need to be generated from scratch.
• Purchase, design and install ungrounded capacitor bank control panel, using Entergy Standard PM070200 as a reference only. The ungrounded control panel for fault interrupter switch (FIS) application will be used, except that the panel will incorporate the ZIV Type BCD Protection and Control Relay in place of the S&C UP and VR relays.
• Purchase, design and install an S&C 69 kV phase to ground resistive potential device according to Entergy Standard PM070200. A resistance type potential device is required to monitor the capacitor bank neutral-to-ground voltage. A single-phase CVT junction box will be used for the neutral voltage.
• Purchase and install one 115kV, 400A Single Frequency Line Trap. Reference Entergy Purchase Standard PM0802, latest revision. This trap will be mounted on the center phase (“A” phase) of the capacitor bank. The unit shall be ordered factory tuned to 166kHz.
• Complete design and installation will be required for the electrical power supply, controls, and monitoring alarms for the one new motor operated switch.
• The AC supply panel has no spare breakers and no spare slots. The DC supply panel has no spare breakers and no spare slots. Purchase, design and install an AC/DC split stand alone panel. This panel will be used to replace the existing
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• To make room for the new split AC/DC panel purchase, design, and install a Satec panel meter for the station metering of transformer #1. This meter will be installed on the transformer #1 differential panel. The existing station metering panel for transformer #1 will be removed creating space for the new split AC/DC panel.
• The existing RTU is a CAMCO 48VDC unit with only three spare status points, this will not be sufficient for this installation. Purchase, design and install a GE Harris D20 RTU. The RTU size specification for this project will be 1A/2S/1K/3KI/125 for indoor installation. The new RTU will need to come equipped with a TRW-S9000 Universal Protocol Converter (UPC) to ensure proper communications to the TOC. The RTU should be ordered with a cabinet, DB25 connectors on all cards and varioface terminal blocks.
• The existing 125V, 100Ah battery set and charger appear to be in good condition and should not have to be changed for the equipment added by the capacitor bank installation project.
• The control house has enough available space for to add the Capacitor Bank Control Panel, RTU, and spilt AC/DC panel.
• Complete design and installation will be required for the AC and DC power supplies, controls and monitoring alarms for the 115 kV Fault Interrupter Switch.
• Following the completion of this project, if no other loads remain on the 48vdc battery, it should be removed.
6.3.3.5 Relay Settings / RTU Configuration Work
• Relay settings will be required for the ZIV Type BCD Protection and Control Relay.
• The D20 RTU will require a configuration package.
6.3.4 Longwood Substation Improvements
There will be no site, foundation or electrical work required. This work will be performed in a substation owned by an adjoining utility. The work will be coordinated through SWEPCO’s work management system.
6.3.5 345kv Transmission Line Cut In
Latticed tower dead end structures are in place which will allow the line to be cut in to the proposed 345kV/115kV Substation with minimal impact to the existing line.
6.3.5.1 Existing Line Data and Required Material for Cut-In
Conductors: 954 kcmil 45/7 Rail
Shield Wire: One 7#7 Alumoweld and one OPGW-2400 on both in and out
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Structures: No new 345kV structure required.
Insulators: 6-345kV Deadend insulators.
Grounding: #0000 copper conductor and grounding copper rod 5/8” diameter, 8’ length, and tied to the substation ground grid.
6.3.5.2 Assumptions for Transmission Line
An outage can be arranged for the 345kv line as necessary.
6.3.5.3 T-line construction
Dead end structures are in place which will allow the line to be cut in to new structures with minimal structural impact to the existing line. The work will consist of removing the jumpers between the existing towers and re configuring them to the buss work installed as part of the substation.
6.3.6 Sarepta 345kv to Sarepta 115kv T-Line
An H-Frame concrete structure will be installed at approximately 310-feet span between the existing 115kV Substation and the proposed 345kV/115kV Substation.
6.3.6.1 Line design
Design loading: NESC (Medium), Extreme wind -25.6lb/ft2, Heavy Ice - 1”;
Conductors: 1272 kcmil, Bittern 45/7, ACSS
Shield Wire: Two 7#7 Alumoweld
Structure: one 90ft-H Frame direct embedded concrete structure will be installed.
Insulators: 3 suspension insulators for the H-frame concrete structure and 6 deadend insulators for the Substation take-off structures.
Grounding: #4 copper clad conductor and grounding copper rod 5/8” diameter, 8’ length;
6.3.6.3 T-line construction
Transmission line construction will be coordinated with substation construction work. The tie in on the Sarepta 345kv end of the line can be made at any time during construction. The connection to the 115kv substation end will have to be coordinated with bus outages.
6.3.7 Sarepta 345kV Substation
As shown on drawing L0475EA1, the substation will include: three 345kv breakers, and one 3 phase 345kv Auto transformer. The plan will be to configure the spacing for a 2nd unit, but not install it until the need exists.
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6.3.7.1 Site Work
The proposed site at Sarepta 345kv is six acres of wooded and hilly area owned by Entergy. A site survey and soil borings are required to firm up the scope of site work. It is desired to perform site construction during a dry time of the year to minimize the impact of erosion.
• Perform a site survey.
• Perform soil borings.
• Develop and implement Storm Water Management Plan controls.
• Clear and dispose six acres of wooded area.
• Strip six acres of topsoil.
• Sterilize five and one half acres of soil.
• Compact approximately 20,000 cubic yards of fill (+/- 30% estimate to be firmed up with site survey).
• Excavate and grade 25,000 cubic yards.
• Seed and mulch 3 acres.
• Install 9,000 tons of limestone.
• Install 3,000 feet of roadway to include a route from the existing 115kV yard to the 345kV yard.
• Install 2200 feet of 8 feet high fence to enclose the 700 feet by 360 feet 345kV area with two 20 feet wide gates and one man gate.
• Install 24 catch basins, 400 feet of 24" culvert, 800 feet of 12" culverts and 200 feet of 48" culverts.
• Install 600 feet of access road from the existing driveway to the new substation.
• Install 700 tons of lime stone on the access road at time of site construction (to be specified separate from site cover live stone)
6.3.7.2 Foundations
A soil resistivity measurements and ground grid analysis are required to design the ground grid according to Entergy standards. Approximately 22,000 feet of 4/0 copper will be required to create thirty-foot square meshes and grounding pigtails.
The following foundations will be required:
• 1 each 345/115kv 3 phase transformer foundation with oil containment
• 3 each 345kV Breaker Foundations
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• 11 each 345kv switch foundations
• 15 each 345kv 22ft three phase bus support foundations
• 16 each 345kv 34ft three phase bus support foundations • 8 each 345kv 34ft single phase bus support foundations
• 34 each 345kv 22ft single phase bus support foundations
• 8 each 500kv 55ft single phase bus support foundations
• 1 each 115kv AM deadend structure foundation (line from 345kv to 115kv substation)
• 1 each 115kv switch support foundation
• 6 each CCVT support foundations
• 3 each CT support foundations
• 9 each arrester support foundations
• 4 each line trap support foundations
• 1200 feet of cable trough inside the substation
• 1 control house foundation (20’ X 50’)
• 15 each yard light foundations
Approximately 3,000 ft of 2” conduit will be required. When the substation is complete, 4” PVC 4’ tall plastic pipe guard/markers should be installed along the cable trough.
6.3.7.3 Electrical Work
As shown on drawing L0475EA1, the substation layout will include 101 each 345kv GSU Standard steel structures should be used. The general configuration is 4 element ring bus with one breaker not installed. This substation will be designed in accordance with standard number ML0501 (Substation Design Parameters).
The Auto Transformer will have the following characteristics (per conference call of 6/26/06) 5-position No Load Tap Changer BIL = SN0103 requires 1175kv BIL Impedance = 12% (determined by planning) Investigate monitoring requirements (Glaser directs to Shawn Jordan)
The following equipment will be installed: • One 3 phase 300MVA 345kv/115kv auto transformer, buried tertiary
• 3 each 345kV 2000A 40kVA gas circuit breakers
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• 10 each 345kV 2000 A vertical break motor operated switches (2 with ground blades); switches shall have LLSII attachment for charging current
• 6 each CCVT supports
• 3 each CT supports • 9 each arrester supports
• 4 each line trap supports
• 243 each 345kv high strength post insulators (Type TR367)
• 15 each 345kv 22ft three phase bus supports
• 16 each 345kv 34ft three phase bus supports
• 8 each 345kv 34ft single phase bus supports
• 34 each 345kv 22ft single phase bus supports
• 8 each 500kv 55ft single phase bus supports
• 1 each 115kv AX2E deadend structure with shield wire extension (for line from 345kv to 115kv substation)
• 1 each 115kv CE switch support
• 1 each 115kv 2000 A vertical break motor operated switches (with grounding blades)
• 18 each 115kv station post insulators
• 2000 ft of 6” schedule 80 aluminum tubing for rigid bus (high bus)
• 3500 ft of 5” schedule 80 aluminum tubing for rigid bus (low bus)
There will be a 20’ X 50’ control house with two battery rooms.
15 yard lights will be installed on separate foundations at strategic locations, determined by the designer.
The substation will be shielded using 7 #7 Alumoweld conductor installed on shieldwire poles located throughout the substation as determined by the designer.
There will be a two 3 phase station service transformer banks on a line from the distribution side of the 115kv substation. This should be coordinated with the local Distribution Network.
6.3.7.4 Relay/Settings/Configuration Work
• The new control house (20’ x 50’) will be able to accommodate two transformer differential panels, AC panel, 2 DC panels, RTU unit, two each 125VDC 200- amphour battery set with racks, two 25amp chargers, 2 DC switching panels, DC voltage transducer, DC inverter, substation communication package and one
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(MOS-6) Control Panel to control 6 motor operated line switches, 4 line panels, 3 breaker control panels • The new power autotransformer will require two transformer differential relay panels. Auto Diff 1 panel will use the SEL 387E for primary high side protection. Auto Diff 1 zone will protect from the high side of the 345kV breakers to the low side of the auto. This panel will also be the secondary 345kV bus protection. Auto Diff 2 panel will use a SEL 387E for low side primary and a NxtPhase T-PRO for the auto diff secondary protection. Auto Diff 2 zone will protect from the high side of the auto to the low side of the 115kV breaker. The secondary auto diff protection will protect from the high side of the auto to the low side of the auto. Both panels will also use a SEL 2506 to convert the inputs and outputs to fiber for signals to the 115kV breaker panel.
• The El Dorado line will be protected by the standard Entergy unblocking line panel which incorporates a SEL 421 for primary protection and a SEL421 for secondary protection. Communication will be a RFL 9780 three frequency unblocking carrier set with all necessary auxiliary equipment needed for testing and maintenance. New transfer trip and unblocking frequencies will be specified by the Entergy Relay Settings Group.
• The Longwood line will be protected by dual SEL 421 relays. The primary SEL 421 will incorporate blocking carrier. The secondary SEL 421 will incorporate unblocking carrier. The SWEPCO panel will use a SEL 421 primary blocking and a GE D60 secondary unblocking. The carrier units (3) will be Pulsar UPLC with their associated balancing transformer (1-Pulsar H1RB) and hybrids (1-Pulsar H1SB-R, 2-Pulsar H1RB).
• The El Dorado line will require two 345kV, 2000A Single Frequency Line Traps and two Single Frequency Line Tuners. These units will be ordered factory tuned to the new frequencies specified by the Entergy relay settings group.
• The Longwood line will require one 345kV, 2000A Single Frequency Line Trap and one Single Frequency Line Tuner for the blocking scheme. The unblocking scheme will require one 345kV, 2000A Three Frequency Line Trap and one Three Frequency Line Tuner. These units will be ordered factory tuned to the existing Longwood frequency.
• Install three high voltage breaker control panels.
• Install six 345kV CCVTs. All CCVTs are to be metering accuracy and shall have carrier accessories installed. Three CCVTs per line.
• Install one CCVT and a single phase CCVT junction box on the 345kV bus.
• Install two, three phase CCVT junction boxes.
• Install three metering accuracy CTs and a CT junction box on the Longwood line.
• Install one high voltage termination cabinet, one high voltage alarm junction box (indoor), and one high voltage alarm junction box (outdoor).
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• A digital fault recorder (specified such that it can be upgraded to include a Dynamic Disturbance Recorder – DDR later) will be installed.3
• It will be necessary to meter the lines coming into and out of the station on the 345kv line to facilitate power transfer interaction with EAI and SWEPCO.The transformer-metering load data will be supplied by the SEL-387E located in the transformer differential panel. There will be a separate meter panel to meter the power flow to SWEPCO.
• Substation voice and data communication circuits, along with their necessary junction boxes, shall be installed. For substation, relaying, metering and RTU communication a telephone line sharing switch and SEL2032 port switcher shall be installed.
• RTU will be 8979 Protocol. RTU will need to include one port for SOC to get data for dial up metering. Telcom needs to request the phone circuit at least 90 days in advance of ISD.
Install the following equipment (summary):
• Two indoor transformer differential panels • Four line panels, 4 SEL 421’s (2 each looking at Longwood and El Dorado) • Three breaker control panels • One AC stand-alone panel • Two DC stand-alone panels • One station service AC panel • Indoor meter panel • One Harris RTU D20 unit • Voice and Data circuits (coordinate with Telecom) • Two 125VDC 200 amphour-battery set • Two 25amp chargers, two battery racks, and two battery test switches • Two, 3 phase and one, single phase CCVT junction boxes • One metering CT junction box • One high voltage termination cabinet • Two high voltage alarm junction boxes • Automatic Transfer Switch • Communication junction boxes (substation interface & control house interface) • One (MOS-6) line switching control panel • Miscellaneous communication equipment • One DC inverter and one DC transducer • 4 line traps (2 per line) • 4 line tuners • 3 CT’s – metering accuracy • 7 CCVT’s – metering accuracy • One DFR with expansion capability to a DDR if possible4
3 per email from Charlie Fink 5-18-06 4 per email from Charlie Fink 5/18/06
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6.3.7.5 Communications
Entergy will require one phone line (POTS) for general service use connected to a port switcher. Entergy will require one RTU Data Circuit to the SOC. Entergy will require one RTU Data Circuit to the TOC. AEP/SWEPCO will require one RTU Data Circuit to their SOC.
6.3.7.6 Metering
Provided by Kathy Truitt (3/24/06 and 7/6/06) and Edin Habibovic: At Sarepta 345KV, for the new metering on the Longwood line.
The existing metering at El Dorado EHV (EAI) is for a “control area tie” with another utility (SWEPCO). The contractual tie meter point will be moved from El Dorado to Sarepta (preserves the meter placement relationship between Entergy and SWEPCO) by installing new meter equipment Sarepta 345kv. The existing metering (at El Dorado) equipment will remain in place and become the inter company (ELI to EAI) meter point.
Both Entergy and SWEPCO will need to modify host computer systems to accommodate transfer of control area tie metering from EAI El Dorado to ELI Sarepta.
Maximum load = 2 * 50 MVA = 100 MVA = 168 amps @ 345KV “Normal” load = 42 MVA = 70 amps @ 345KV Minimum load = 20 MVA = 33.5 amps @ 345KV
Maximum continuous current rating of lines/breakers at interconnection: 298 MVA = 500 amps @ 345KV (auto at El Dorado is limiting element), but other elements are rated at 2000 amps.
Based on the above loading criteria, the recommended CT specifications for the new metering at Sarepta on the Longwood line are as follows:
3 each of CT Ratio = 600:5, RF = 2, Metering Accuracy 0.15S @ B1.8. These CT’s would be “accurate enough” from 30 amps to 1200 amps, and would have a maximum capacity of 1200 amps. It is imperative that 0.15s accuracy be purchased (as opposed to 0.15 or 0.30) since these are the only metering CT’s guaranteed to be accurate enough down to 5% of full load rating. Keep in mind that these CT’s will become the limiting element for load flow on the Sarepta-Longwood 345KV line (1200 amps).
6.3.7.7 SCADA
Item/Description Quantity Add Remove Automatic transfer switch 1 X Motor Operated Switches 6 X Battery Chargers 2 X 345kV Breakers 3 X RTU 1 X Relays 12 X Auto Transformer 1 X 345kv Switches 10 X 115kv Switches 1 X
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6.3.8 Sarepta 115kV Substation
All equipment will be evaluated to ensure the increase in fault current does not overrate any equipment.
The overall summary of work will include installing a breaker to source the new substation onto the operating bus only in the existing substation, install bus protection and install circuit switchers on the two transformers.
6.3.8.1 Site Work
Entergy Environmental has asked that the project include limestone/gravel addition at the existing substation for spill control however this is not project necessary and will not be included.
6.3.8.2 Foundations
Some foundations are in place for a new line bay already. The existing foundations are identified below. All other foundations are new.
• 115kv 2000A 40KA gas breaker (existing)
• 1 each 115kv AM tower foundation (existing)
• 1 each 115kv CE switch support foundation (existing)
• 3 each 115kv E tower foundations
• 2 each 115kv bus support foundations
• 2 each Series 2000 circuit switcher foundations
The two substations will be connected with 413’ of poured in place duct bank. Conduits should be sufficient for control cables for two transformers with separate bus feed points plus 50%.
Additionally the ground grid of the two substations will be connected by three independent buried copper ground wires.
6.3.8.3 Electrical Scope
This substation will be designed in accordance with standard number ML0501 (Substation Design Parameters).
The electrical scope will consist of installing the following equipment: • 1 each 115kv AM tower with one switch support
• 2 each 115kv circuit switches – series 2000
• Replace two 600 amp 115kv vertical break switches (switches on breaker R6455) with 1200 amp switches
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• 2 each 115kv 2000 amp vertical break switches for the new breaker (1 with ground switch on AM tower)
• 1 each 115kv 2000A 40KA gas circuit breaker
• 1 each 115kv CE switch support tower
• 3 each CVT 115kv E towers
• 48 each 115kv station post insulators
6.3.8.4 Relay Scope
The new power auto transformer will require a 115kV breaker and breaker control panel. A 115kV bus differential panel using the 587Z will be installed. A split AC/DC panel will be installed. The RTU will be upgraded with ME++ chips, K card, and a S card.
Install the following equipment: • Bus differential panel
• Split AC/DC panel
• RTU cards: ME++, K, and S
• 3 - 115kV CCVTs
• 1 – CCVT junction box
• Breaker Control panel
• 12 slip over CT’s
6.4 SOC Notifications/Modifications
The SOC will be notified of the project so that they can make necessary upgrades to necessary power flow models and software.
SOC will be required to make host computer changes to include display screen changes, calculations, and models. SOC has been notified and is providing input into the project.
6.5 DRAWING INDEX See Attached EXCEL File.
7 PROJECT ORGANIZATION
This project will follow the normal flow path of internal customer projects and will not require any unusual project organization. The customer is Transmission Planning.
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8 MATERIALS MANAGEMENT PLAN 8.1 Strategy
The strategy will be to purchase all material new. Some items will be purchased with “before 12/07” delivery dates and the remainder will be purchased with “do not ship before 1/1/08” delivery dates to ensure the appropriate cash flows are followed. There are no abnormal materials or requirements for this project, therefore everything will follow the normal materials process.
8.2 Long Lead Time Major Equipment
Quantity Material Description Use *Lead Time (weeks) 1 Relay panel Eld 34
1 21.6 MVAR Cap Bank Em 3 115kv CVT’s Em 1 115kv Line trap Em 1 115kv 48vdc Mark V Circuit Switcher Em 18 1 115kv 2000 Amp vertical break switch Em 16
1 Transformer, 345/115kV, 300MVA NLTC, 3 phase S345 32 3 Breakers, 345kV, 2000A, 40KA S345 26 9 345kv single phase arrester Pedestal S345 14 42 345kv single phase bus support pedestals S345 14 31 345kv three phase bus support pedestals S345 14 8 500kv single phase bus support pedestals S345 14 2 345kv Line Trap support structures S345 14 6 345kv Single phase CCVT pedestal S345 14 9 345kv surge arresters S345 16 8 345kv 2000A switches w/ motor operators S345 26 2 345kv 2000A switches w/ ground & motor operators S345 26 243 345kv station post insulators (TR367) S345 20 1 115kv CE Switch tower S345 14 1 115kv AX2E deadend tower with shieldwire extension S345 14 6 345kv CCVT S345 12 1 SEL2032 S345 2 SEL 387 S345 1 SEL 587Z S345 4 SEL 421 S345 4 Line Panels S345 3 Breaker Control Panels S345 1 RTU Harris D20 S345
4 115kv 2000A vertical break switches S115 16
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1 Breaker1, 115kV, 2000A, 40KA S115 18 2 Circuit Switcher, 115kV, Model 2030 S115 18 1 115kv CE Switch tower S115 14 48 115kv station post insulators S115 20 1 115kv AM tower with switch support S115 14 3 115kv CCVT S115 12 1 SEL 387Z S115 26
1 Concrete H Pole Structure S115 Line 26 Eld = Eldorado Substation Em = Emersion 115 Substation Lgw = Longwood Substation S345 = Sarepta 345 Substation S115 = Sarepta 115 Substation
All long-lead material will be scheduled and tracked closely using the Material Tracking Report provided by Project Support Services. Vendor data submittals shall be scheduled and tracked.
8.3 Bulk Materials – N/A 8.4 Storeroom Materials – BOM’s 8.5 Vendors – Standard vendors for Substation equipment 8.6 Use of System Spares – N/A 8.7 Use of Temporary Equipment – N/A 8.8 Salvaged equipment – N/A 8.9 Use of System Spares – N/A 8.10 Monetary and Reporting – N/A 8.11 Receipt Procedures – N/A 8.12 Special Considerations – N/A
9 RESOURCE PLAN
9.1 Contracting Strategy
Design work will be performed with internal resources.
Work at Eldorado and Emerson will be handled by the EAI Construction and AM Organizations Work at Sarepta will be handled by the ELI-N Construction and AM organizations
Construction work (T-Line, Site, Foundations and Erection) will be performed via bid contract work.
Final testing will be performed using internal resources.
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9.2 RFQ – to be handled by Construction 9.3 Bid Receipt – to be handled IAW Entergy Commercial Business Policies 9.4 Commercial Bid - to be handled IAW Entergy Commercial Business Policies 9.5 Technical Bid - to be handled IAW Entergy Commercial Business Policies 9.6 Typical Project Execution Bid – N/A 9.7 Bid Submission - to be handled IAW Entergy Commercial Business Policies 9.8 Bid Review Objectives - to be handled IAW Entergy Commercial Business Policies 9.9 Alignment with overall project – N/A 9.10 Contract Administration – Contracts will be administered by Construction
10 PROJECT CONTROLS PLAN 10.1 Project Work Orders
TS9376 Eldorado Modifications TS9375 Emersion Substation TL4xxx 345kv T-line TS9370 Sarepta 345kv Substation TS9377 Sarepta 115kv Substation TL4xxx Sarepta 345kv to Sarepta 115kv
10.2 Cost Management Plan
Project costs will be monitored IAW standard department methods.
10.2.1 Baseline Estimates
The baseline estimate for Sarepta and the LD-Pro baseline estimate for cut in have both been generated and may be reviewed and referenced as an extension of this PEP.
10.2.2 El Dorado Substation TS9376
The relay tasks involve installing various relay upgrades. A construction contingency of 5% will be added to the estimated values to account for technical issues.
10.2.3 Emerson 115kV Substation (EAI) TS9375
The work at Emersion involves significant upgrades to an old substation. Typically, there are many unknowns in this situation. A construction contingency of 5% will be added to the estimated values to account for technical issues and unknowns.
10.2.4 Eldorado to Longwood Transmission Line Cut In TL4xxx
T-Line work work. The actual work is very minimal, therefore no contingency will be carried on this project.
10.2.5 Sarepta 345kV to Sarepta 115kv T-Line
The amount of line work is very small, about 600’ so the actual contingency will be small but the percentage will remain at 5%.
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10.2.6 Sarepta 345kV Substation TS9370
The actual substation is not relatively large. However, considerable site work (dirt work) is necessary for this project. Inclement weather may slow down construction considerably. Extra time is allocated in the schedule to accommodate wet conditions. 5% is being set aside to address civil and site contingencies. Once the site and civil work is complete, most of these funds should be release back to the budget pool for other projects.
10.2.7 Sarepta 115kV Substation TS9377
The work in this substation is upgrade work which historically is difficult to estimate due to the “finding the unexpected” issues. A construction contingency of 5% will be added to the estimated values to account for technical issues.
10.3 Time Management Plan (Scheduling)
See schedule in Project 2000 for start/end dates of planned work activities, including outages. The objective is to continue to work this project as a continuation of Sarepta.
10.4 Change Management Plan
Change management will be IAW with PMO department policies. 10.5 Project Reports
Project Reporting will be IAW with PMO department policies.
10.6 Milestones
Milestones will be documented in the project schedule.
10.7 Gate Reviews
Gate Reviews will be done IAW with the process.
11 QUALITY ASSURANCE PLAN
All work will be done IAW Entergy standards of design and construction. All contract work will be inspected prior to final acceptance by the OC on the job site. All electrical equipment will be tested prior to placing the station in service.
12 CONSTRUCTION MANAGEMENT PLAN
12.1 Site Construction Strategy
S345: Grading works is planned to be performed in Summer 2007 which is preferable for dryer working conditions.
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S345: Foundation work should begin in the fall of 2007 with electrical work to follow in Winter/Spring 2007/2008 for a June ISD. Delivery of the transformer and 345kv line breakers will be in spring of 2008.
S115: Reconfiguration and upgrade work in the Sarepta 115kv substation should begin in Spring 2007 and be completed by the end of 2007.
ED: Relay work in Longwood and Eldorado should be performed in the fall 2007.
T-Line: The transmission line work will include the installation of two dead-end structures to cut the line from Eldorado to Longwood and then span each section into the substation. This will require an outage to this line section and will be scheduled toward the end of the electrical and relay construction phases of work. The outage should be one week in duration. At this time relay work is planned to be performed by the AM group with internal resources.
LG: Work at Longwood will be coordinated with AEP.
Emerson: The work at Emerson is not dependant on any other portion of the project and will be scheduled as necessary to balance work loads.
The major material is scheduled for delivery to match major work activities.
Relay testing and check out will occur immediately after construction. Relay testing will be conducted by AP/AM internal resources.
12.2 Organization – N/A 12.3 Construction Standards
Construction will be IAW Entergy standards. 12.4 Project Execution
See construction plan. 12.5 Safety – Special considerations
There are no abnormal safety situations in this substation.
13 RISK MANAGEMENT PLAN 13.1 Risk Identification
The primary risks are: Funding approval Equipment pricing Scheduling bus outages at S115 Scheduling 345kv Line outages Coordinating relay work with AEP
14 REGULATORY & ENVIRONMENTAL COMPLIANCE PLAN(S)
The following required surveys, studies and assessments include: Environmental assessment of the Sarepta Site
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15 START UP AND TURNOVER PLANS
Entergy AM/AP will test and place the station on line.
16 PROJECT CLOSURE
16.1 Scope Verification
16.2 Project Critique – N/A
16.3 Lessons Learned
Lessons Learned from other substation construction projects have been factored into this project. Other issues that arise should be documented. 16.4 Project Closeout process
The project will be closed out IAW the process.
17 ADMINISTRATIVE PLANS (S)
N/A
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18 COMMUNICATIONS PLAN
Project Team
Name Position Location Tel. E-Mail Charles Newell Program Manager L-AT&T 504-463-2482 ENTERGY Moon Mullins D Project Manager L-AT&T 504-463-2484 ENTERGY
Paul Liest Construction Manager M-TOMB-28 601-351-4227 ENTERGY Construction ENTERGY Will Hobdy M-MAYS-18 601-368-1625 Engineer Construction ENTERGY Charlie Gambrel M-TOMB-28 601-351-4127 Engineer Paul Legrand T-Line Engineer L-AT&T 504-463-7062 ENTERGY Hong-to Lam T-Line Engineer L-AT&T 504-463-7104 ENTERGY Tim Kern Relay Engineer L-AT&T 504-463-2942 ENTERGY Gerald Sachatano Design Engineer L-AT&T 504-463-7082 ENTERGY Stacy Hamilton Design Engineer L-AT&T 504-463-2951 ENTERGY Marnie Roussel Design Engineer L-AT&T 504-463-7316 ENTERGY Gerard Highstreet Settings Engineer L-SCH- 985-902-2568 ENTERGY Construction manager ENTERGY Paul Chamoun A-TDS-CM 501-490-5516 EAI Construction ENTERGY Scott Jordan A-TDS-CM 501-490-5558 Engineer (EAI) Claude E. Smith AEP Project [email protected] AEP/SWEPCO 918-599-2074 Management Mike Webb OC - EAI A-TDS-CM 501-490-5553 ENTERGY Tammy Adams ROW L-WMO-ONT 318-651-6267 ENTERGY David Clem T-AM – EAI A-HOTS-S&O 501-620-5613 ENTERGY James Von Puska T- TOC A-9LA-TDC 501-396-4982 ENTERGY Edin Habovic Transmission Planner L-SCH 985-902 ENTERGY Transmission ENTERGY Milton Bostich L-WMO-ONT 318-651-6275 Operations Ed Brinson TOC – ELI-N L-WMO-400 318-329-5454 ENTERGY Transmission ENTERGY Bob McQueen Account Manager L-SCH 985-902-2630 (SWEPC Contact) Troy Malborough Scheduler L-AT&T 504-463-7093 ENTERGY Kathy Truitt Metering L-VIR-688 504-365-3647 ENTERGY William Aycock SOC A-SOC-1 501-541-3912 ENTERGY Polly Irons SOC A-SOC-1 501-541-3966 ENTERGY
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18.1 Record of Critical Communications
• PEP J.E.T. Meeting 3/21/06 (Beaumont) • Entergy Metering/PM – metering plan – 3/24/06 email • Entergy/AEP Conference Call – set up communication channels 5/16/06 (Mullins, Kern, McQueen, AEP) • PM/TSP - 3 Phase/1 Phase – 5/16/06 (Hammond)- email out to team with results • Entergy Internal Relay Philosophy – 5/17/06- Kern, Mullins, Daigle, Clement, Glaser, Wahl • PM/SOC – Mullins, Aycock 5/17/06 • PM/TOC – Mullins, Brinson 5/18/06 • PM/Fink – DFR/DDR 5/17-18/06 email • PM/SOC/Design/Metering – Mullins, Kern, Clement, Truitt, Aycock (6/13/06) – metering requirements • PM/Polly Irons – SOC Data Requirements – 6/15/06 • Remedy Case to Telcom documenting Telephone needs 6/15/06 • PM/EAI – Mullins, Chamoun, Clem, Nix – establishing EAI team members 6/21 & 6/26 • EMCC/Planning – 3 phase transformer – Mullins, Roussel, Kern, Sachatano, Keltner, Powell, Khan V., E. Habidovic, Gambrell 6/26/06. • Entergy/AEP – Mullins, Aycock, McQueen, Droddy, Copeland, Irons, AEP: Smith, Park, Jackson – Metering Philosophy 7/6/06 • Entergy /AEP – failed conference call July 24, Rescheduled to July 31, Rescheduled to 8/15 • Entergy – Sarepta 115kv scope – Mullins, Leist, Gambrell, Sachatano, Brinson – discuss scope of work on reworking old Sarepta 115kv substation. 7/15/06 • Entergy – Emerson Scope – Mullins, Hamilton, Jordan, Wahl – discuss scope. 8/1/06 • Mullins, E. Berberich – Telcom in EAI on scope needs. • Entergy and AEP - Telcom (Mullins, McQueen, Kern, Wahl, Sistrunk, Cooley, Moss, Jackson, Dowdy, Williams, Smith, Micha) – discussed details of Sarepta to Longwood relay scheme. 8/22/06 • Entergy PEP Review – Mullins, Leist, Lapeyrouse, Newell, Parish, Story, Clement – 9/11/06
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19 LIST OF ATTACHMENTS TO THE PROJECT EXECUTION PLAN.
Item Method Location A PDCR E-Room B Estimate(s) Eroom under Estimate Summary
C Schedule Project 2000 (Mullins) D List of Drawings with Associated Under development Manhours E Switching One-line Diagram (SO1) Under Development. F Operational One-line Diagram Under Development. (OP1) G Relay One-line Diagram Under Development. H Electrical Arrangement E-Room and/or e-mail attachment. I Site/Plot/Fence Plan e-room
J Control House Arrangement Under Development K Phasing Diagram Under Development L Plan and Profile Under Development M Staking Sheet T-Line Design N Transmission Operation Map n/a O List of Applicable Specifications Standards and Standards P Digital photos files saved in E-Room Q Communication Documents files saved in E-Room
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