ApprovedJ A.pdf

Control No: CECT‐MVM‐13‐02

Enclosure 1

Enclosure 2

Enclosure 2 (cont.)

Enclosure 3

Enclosure 3 (cont.)

Enclosure 4

Enclosure 4 (cont.)

Enclosure 5

TRANSMISSION LINE & SUBSTATION PROJECTS

COMPANY:EAI

CUSTOMER: US-COE

FACILITIES STUDY

EJO # : F4PPAR0494

COMPANY: EAI

PROJECT NAME: BAYOU METO BORING PUMP STATION

2008114ARED

Revision:

Rev Issue Date Description of Revision Prepared

By Approved

By

A 10.7.11 1st Draft, Team input RP AH

B 11.07.11 2nd Draft, for JET voting RP AH

0 11.10.11 Issued to TPD RP AH

0A 11.11.11 Format Edits GWR

0B 11.18.11 Added Environmental Impacts GWR

* Note: All required JET approvals and other stakeholder concurrences are shown in the voting polls in eRoom.

Enclosure 6

Bayou Meto Pump Station # 1 Rev.0B 11.18.11

TABLE OF CONTENTS

1.0 PROJECT SUMMARY

1.1. Background and Project Need

1.2. Scope Summary

1.3. Cost Summary

1.4. Schedule Summary

2.0 SAFETY REQUIREMENTS

3.0 GENERAL ASSUMPTIONS

4.0 SCOPE OF WORK

4.1 Substation: Scott 115kV/13.8kV Substation

4.2 Transmission Line: Bayou Meto Substation Cut-In

4.3 Distribution Scope:

5.0 COST

6.0 SCHEDULE

7.0. RISK ASSESSMENT

8.0 TABLE OF ACRONYMS

9.0 ATTACHMENTS

A. Scope Summary Diagram / Area Map B-1 One Line Drawings – 115kV/13.8kV Station B-2 One Line Drawings – 13.8/4.16kV Station C. Duration Schedule D Environmental Review

Enclosure 6 (cont'd)

Bayou Meto Pump Station # 1 Rev.0B 11.18.11

1.0 PROJECT SUMMARY

1.1. Background and Project Need

A request has been made by a consulting engineer to add a new pump station near Scott, AR. The station would have 2 – 500 hp motors and 4- 1500 hp motors (7000 hp total). This station would provide irrigation water for the surrounding areas from the Arkansas River. A request was made to provide two separate transformers to provide an installed spare. The voltages would be 4160 V for the 1500 hp motors and 4160 V for the 500 hp motors. Also, a request to provide a cost estimate for a pad mounted transformer to supply 480/277Y V was made. A later request was also made to supply the 7000 hp motor load with a single transformer at 4160 V.

Motor data was not provided by the customer. The following is the assumed motor characteristics as provided by ASPEN Modeling. (This study was completed using 750 hp motors instead of the revised 500 hp motors.) The motors are shown in the starting order. The motor start impact to the 115 kV gird was reviewed.

1st 2nd 3rd 4th 5th 6th High Side Voltage 115 115 115 115 115 115 Motor HP 905.19 905.19 1810.38 1810.38 1810.38 1810.38 Motor kV 13.8 13.8 13.8 13.8 13.8 13.8 Motor Efficiency 0.9000 0.9000 0.9000 0.9000 0.9000 0.9000 Motor Power Factor 0.9000 0.9000 0.9000 0.9000 0.9000 0.9000 Motor Service Factor 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 Motor MW 0.75 0.75 1.50 1.50 1.50 1.50 Motor MVAR 0.36 0.36 0.73 0.73 0.73 0.73 Motor MVA 0.83 0.83 1.67 1.67 1.67 1.67 Motor Amps 34.86 34.86 69.73 69.73 69.73 69.73 Motor Start Power Factor 0.0750 0.0750 0.0750 0.0750 0.0750 0.0750 Static Load MW 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 Static Load MVAR 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 Static Load MVA 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000

1.2. Scope Summary

The overall scope of this project is summarized as follows:

A new 115kV Transmission substation will be built under the existing AECC Baucum to AECC Keo 115kV T-line and a single distribution circuit will be installed to the pump station facility. A Distribution substation will be built at the pump station site to provide service to the facility.

Scott Substation: (1) 115kV/13.8kV – 10MVA – Tap Substation Distribution Line: Approximately 3 miles of 336.4 ACSR -13.8kV Distribution Line.

Bayou Meto Pump Station # 1 Rev.0B 11.18.11

1.3. Cost Summary

The estimated total project cost is $6.57 Million. This cost includes an Allowance for Funds Used During Construction (AFUDC) but does not include Tax Gross Up which may apply.

1.4. Schedule Summary

The Proposed ISD for the overall project will be based on the customer formal approval of the project and funding agreements being executed. The preliminary ISD is not known at this time. The customer has indicated the pump station completion date is scheduled for 2016.

2.0 SAFETY REQUIREMENTS

Safety is a priority with Entergy. Safety will be designed into substations and lines.

The designs will be done with the utmost safety for personnel in mind for construction, operation, and maintenance of the equipment.

All employees working directly or indirectly for Entergy shall adhere to all rules and regulations outlined within the Entergy Safety manual. Entergy requires safety to be the highest priority for all projects. All Entergy and Contract employees must follow all applicable safe work procedures.

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

3.0 GENERAL ASSUMPTIONS

• Estimates based on one transmission line routing. Upon funding CCN may identify alternate route

• ROW availability has been assumed.

• Detailed interconnection studies (such as relay impact, ground resistivity, motor start analysis, soil borings & other geo-technically) have not been completed.

• Entergy will not perform work on customer owned facilities and is not included

• Schedule milestones after design and constructability review and environmental and regulatory compliance have not been determined. Best guess on SWPPP creation, implementation and monitoring can vary greatly dependant on outcome of environmental studies

• Wetland mitigation is undetermined until all environmental analysis is complete.

• Project duration does not begin until all relevant agreements are executed

• Unknown underground factors will add mitigation costs and may impact schedule

• Rising steel, copper, fuel and other market conditions could greatly affect estimated cost.

Entergy ROW acquisition guidelines require an Environmental Phase 1 Analysis study to be performed for the proposed Substation Site and Access road.

Bayou Meto Pump Station # 1 Rev.0B 11.18.11

4.0 SCOPE OF WORK

4.1 Substation: Scott 115kV/13.8kV Substation

Assumptions

No survey is available and three feet of fill is required to raise the substation site to the final elevation.

Fill will be used only on the initial site area being developed per the one-line and electrical arrangement drawing; undeveloped site area will be cleared and fenced.

Soil conditions are such that no special grounding is required and a standard 40’ x 40’ grid is adequate.

Soil conditions facilitate the use of drilled pier foundations.

The site location is not considered wetlands; however, oil containment is required.

Site clearing of trees is required with moderate brush An existing distribution feeder is located near the new substation to provide a source for backup station service.

Transmission and distribution lines access to substation is as shown on the attached electrical arrangement drawing Roadway entries (2) into substation will be built with a 28 foot gate at each entry.

Guard service is required to protect materials/equipment for 6 months.

Site Work

Site preparation including waste disposal, excavation, grading, backfill, dirt compaction, crushed rock and site drainage shall be performed in accordance with Entergy Standards and drawings. Site preparation work shall include the furnishing of all labor material, transportation, tools utilities, equipment, appurtenances, and performance of all operations necessary for excavating, filling, grading, and re-surfacing the working area.

The following site work includes:

• Waste disposal, excavation, grading, and site drainage for approximately 1 acre site.

• Clear and grub approximately 1.5 acres of land for the construction of the substation. The footprint of the substation (200’ x 232’ including perimeter grounding) shall be sterilized.

• Install approximately 8200 cubic yards of structural fill material required to raise the final elevation of the substation pad 3’ above the surrounding areas.

• Install perimeter 850’ fence for developed substation area including 2-28’ gates.

• Install perimeter 400’ fence for undeveloped area of site.

• Install 2-50’ access roadways to 2 entries including 2-24” diameter culverts

30’ each.

• Install approximately 2400 tons of crushed rock after conduit and ground grids are installed for ground cover and access road.

Bayou Meto Pump Station # 1 Rev.0B 11.18.11

Build 1000ft long access road from existing farm road to the proposed substation location.

Foundation Work

The following foundation work is required:

• Install 3 - 115kV dead-end foundations in HV bays

• Install 5 - 115kv Low Bay Switch structure foundations (3 switches and 2 w/BK1 brackets)

• Install 12 – 115kv 1 PH Low bus support foundations

• Install 7 – 115kv 1 PH High bus support foundations

• Install 1 – 115kv Circuit switcher foundation

• Install 1 – Control House foundation set (24’ x 24’ - drilled piers)

• Install 1- 115kV/13.8kV LTC, 12MVA Transformer foundation including containment

• Install 1 – 115kv Transformer dead-end foundation (2 columns)

• Install 1 – MV breaker bay steel foundation (2 columns)

• Install 1 – 15kv breaker foundation

• Install 4 – yard light foundations

• Install 80 feet of cable trough from control house to transformer area

• Install 2 pull boxes for conduit system

• Install 2” and 4” PVC from pull boxes (~1000 feet) to cable trough and electrical equipment

• Install 2800 feet ground grid using 4/0 copper conductors

• Install 1200 feet ground grid “pigtails” for equipment and fence from ground grid using 19#9 copper-weld

Electrical Work

The following Electrical work is required:

• Install 3 - 115kV dead-end structures in HV bays

• Install 12 – 115kv 1 PH Low bus support structures

• Install 7 – 115kv 1 PH High bus support structures

• Install 31 – 115kv polymer post insulators (19 for bus supports and 12 for dead-ends)

• Install 5 - 115kv Low Bay switch structures (3 switches and 2 w/BK1 brackets)

• Install 2 – 115kV, 2000A, GOAB, LBS (Type LLSII) Switches w/ground and

125VDC Motor Operator

• Install 1 – 115kV, 1200A, GOAB disconnect switch w/ 125VDC motor operator.

• Install 27 – 115kv porcelain post insulators (for switches)

• Install 1 – 115kv Circuit switcher and associated structure

• Install 6 – 115kv Suspension polymer insulators from HV bay to transformer

DE

Bayou Meto Pump Station # 1 Rev.0B 11.18.11

• Install HV bus using approximately 1600 feet of 4” Schedule 40 Al tubing and 1600 feet of bundled (2) 954 ACSR (45/7) aluminum conductors and dampener cables;

• Install 1 – Control House

• Install 1- 115kV/13.8kV LTC, 12MVA Transformer

• Install 1 – 115kv Transformer dead-end structure

• Install ~260 feet of shield wire from transformer dead-end to HV bay dead-end

• Install 4 – 15kV Fused disconnect switches on transformer dead-end (for metering PT’s and SS transformer)

• Install 1 – 25KVA Station service transformer on transformer dead-end

• Install 1 – 240VAC safety switch on transformer dead-end

• Install 3 – 15kV PTs on transformer dead-end

• Install 3 – metering CTs on MV bay steel

• Install 1 – MV breaker bay steel structure (2 columns)

• Install 9 – 15kV polymer post insulators (3 on transformer dead-end and 6 in

MV bay)

• Install 3 – 15kv Line Arresters on MV steel structure

• Install 6 – 15kV hooksticks, 1200A

• Install 1 – 15kV, 1200A, GOAB by-pass switch, w/ manual operator

• Install 1 – 15kv breaker

• Install 4 – yard lights

• Install above ground conduits to electrical equipment

• Connect/Install ground grid “pigtails” for equipment, structures and control house using 19#9 copper-weld.

Relay:

Assumptions:

The station with be equipped with a new Waukesha LTC Transformer The station will be equipped with a leased T1 communication line.

There will be an alternate emergency AC source available.

Equipment:

• Size, purchase and install one (1) 125V DC Battery Set.

• Purchase and install one (1) battery charger per Entergy Standard PM 0302.

• Purchase and install one (1) AC transfer switch per Entergy Standard

PM3401.

• Purchase and install one (1) battery switching panel per Entergy Standard

PM1003.

• Purchase, design and install one (1) AC/DC split panel per Entergy Standard

PM0101.

• Purchase and install one (1) RTU.

• Purchase and install three (3) 70:1 CCVTs

• Purchase, design and install one (1) low voltage CCVT junction box.

Bayou Meto Pump Station # 1 Rev.0B 11.18.11

• Purchase and install one (1) Main/Feeder Breaker Transformer Differential Panel differential relay per Entergy Standard PM3505 OPT A.

• Purchase, design and install one (1) Motor Operated Switch Control Panel (MOS-2) per Entergy Standard PM2201.

• Purchase, design and install one (1) outdoor AC panel. This panel will serve the control house and transformers.

• Complete design and installation with be required for electrical power supplies, controls, monitoring alarms, analog data and communications for the following devices as applicable.

One (1) 115/13.8 kV, 12MVA LTC power transformer.

One (1) 115Kv S&C series 2000 circuit switcher.

• Purchase and install one (1) demarcation box for lease T1 line communication.

• Purchase and install one (1) satellite clock

• Purchase and install one (1) telephone gauntlet SLSS

• Purchase and install (1) revenue meter panel

Relay Settings: Scott 115/13.8kV Substation General:

• Entergy will observe and apply NERC/SERC Regulatory compliance FAC- 009, PRC-001, and PRC-023 per requirements.

• New RTU configurations or revisions will be necessary.

• Relay settings and RTU configurations details need to be specified during

Project Execution (PEP) Plan stage, such as equipment and schemes for pilot protections.

• System changes will be modeled in ASPEN. Relay Impact Analysis will be performed by a settings engineer during PEP stage to identify requirements for relay/CT replacement and settings revisions at the local and remote stations in the area. Some obsolete relays may need to be replaced.

• Entergy will provide off site/on site relay settings support during construction for setting database issues, relay software and firmware compatibility.

• Develop new relay settings for transformer differential and main breaker settings at Scott per Entergy PM3505 Option A. (assuming Feeder settings will be taken care by the customer or Asset management group)

• Possibly revise settings at Lynch looking towards P.B. Dierks ()

• Possibly revise settings at P.B. Dierks looking towards Lynch

Communications and SCADA: No RTU currently exists at this site. A new RTU will be installed for station communications.

Metering: Entergy will meter this customer at the 13.8 kV bus at the Scott 115kV Substation - 13.8kV Substation. Meter data will be communicated from this station to the Entergy TOC via leased T1 service to this station.

Bayou Meto Pump Station # 1 Rev.0B 11.18.11

4.2 Transmission Line: Bayou Meto Substation Cut-In

The new substation will be constructed below 115 kV line #972.1 (Baucum – AECC Keo) between structures 339 and 340, adjacent to Scott Road. The existing line is wood H-Frame construction and the conductor is 4/0 AWG copper 12 strand. In order to facilitate construction of the switch towers, Entergy will install a temporary prop structure. The prop structure is assumed to be a 110 foot direct embedded delta braced post steel tangent pole with shield wire davit arms.

The pole will be placed on the T-Line center line, 20 feet outside of the northwest fence of the substation. This will provide safe working clearance above the existing ground elevation at the two switch tower locations. No other structures need to be modified for this temporary phase.

To provide 115 kV to the substation, two three-pole guyed concrete deadend structures will be placed approximately 60 feet outside of the sub fence, on either end of the sub. These will be guyed towards the substation. From the deadend structures, the phase conductors will slack into the pull off towers. The shield wires will be strung across the sub from new deadend structure 339-1 to new deadend structure 339-2.

• Line Length – Approximately 400 ft. between new structures.

• Structure Types:

Temporary Prop Pole - single pole, galvanized tubular steel Permanent Structures – three pole, guyed concrete

• Minimum Ground Clearance – 26 feet

• Number of Structures – 2 permanent,1 temporary

• Conductor – 666 MCM ACSR (Flamingo)

• Shield Wire – 7#7 Alumoweld (over the substation)

• The structures will be directly embedded. It is assumed that the permanent structures will be direct embedded with concrete backfill.

• 21 insulators are estimated for this project.

• Approximately 800 pounds of 666MCM ACSR conductor will be required for this project.

• 800 feet of 7#7 Alumoweld shield wire is estimated for this project.

• Soil borings have not been provided.

• Risk - $10,000.00 has been included for risk to cover the potential for material price increases, requirements for larger poles and/or foundations.

This money may be deducted once the Constructability Review is complete if not needed.

Bayou Meto Pump Station # 1 Rev.0B 11.18.11

4.3 Distribution Scope:

An overall review was made of the proposed location of the canal from the Bayou Meto Pump Station to the east. To avoid interference with the canal construction and the 13.8 kV service and the need to have power at the station prior to the completion of the canal, EAI Distribution will rebuild its existing line and extend service to the Pump Station. EAI will replace existing poles along and re-conductor it's circuit from 1/0 ACSR to 336.4 MCM ACSR conductor to accommodate the load at the Pump site.

EAI will primary meter (13.8 kV) at the facility and will require a dial-up phone line to the meter. Two 5000 KVA 4160Y/2400 volt and 1-300 KVA 480Y/277 pad mounted transforms will be installed on the customer provided pad. The customer will extend the 4160/2400 V & 480/277 V service underground into the pump station motor control center.

The estimated time to complete final design is approximately 2 months and construction will take a minimum of 8 months.

5.0 COST

An analysis will be completed and determination made as to whether the project will be funded by the customer via pre-paid CIAC (Contribution in Aid of Construction) payments, or minimum billing. Depending on the outcome of that analysis, if a contribution from the customer is made, a Tax Gross Up (TGU) payment would be required, at the applicable rate at that time. TGU is not currently included in the estimate.

Projected Costs

Project Component Cost

Scott 115kV Substation $3,598,340

Scott Substation T-Line Cut-in $444,009

Distribution Line Circuit and Distribution Substation $1,618,577

Environmental Impact (See attachment D) $743,752

Over Head Loaders for Environmental $165,376

Project Estimated Total Cost $6,570,054

6.0 SCHEDULE

• All construction work requiring outages will be performed during acceptable periods of system load flow, which most often is the off-peak load season. Line outages will be discussed with the SOC and TOC and the assumption is made

Bayou Meto Pump Station # 1 Rev.0B 11.18.11 that line outages will be executed as planned. However, last minute denial of outages by the SOC/TOC along with resulting schedule delay is possible.

• Substation construction will be coordinated with the transmission line outages when possible.

• Construction resources are available when required.

• Transmission Line and Substation projects will begin subsequent to Definition phase Project Execution Plan.

• This schedule does not account for adverse weather conditions.

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

• The table below lists the major tasks to be completed. When the selection option is defined, approximate dates will be indicated.

Project Phase Proposed Duration Definition 120 Days

Detailed Design 120 Days Regulatory (If Needed) 270 Days

Construction 180 Days

Notes to Duration Schedules: The project Definition phase commences with project approval, and a executed funding reimbursement agreement being in place, along with an executed notice to proceed being received by Entergy. The Regulatory and CCN process can be completed in parallel with the project Definition and Preliminary Design phases. Construction cannot start until the CNN process is complete.

Bayou Meto Pump Station # 1 Rev.0B 11.18.11

7.0. RISK ASSESSMENT

The following table contains risk events that may impact cost and/or schedule during execution of the project.

Risk Comment Impact

Underground site issues (Pipelines, wells, containments)

Unknown underground factors will add mitigation costs and may impact schedule ***

Substation Site will require substantial site work

Site may be in flood plain, wetlands, Soil Contamination ***

Material transportation could affect cost/schedule

Large transformers(other equipment) may require special transport to substation site **

Material costs steel & Equipment

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

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

Storm-water plan implementation

Best guess on SWPPP creation, implementation and monitoring can vary greatly dependant on outcome of environmental study. **

Weather & Equipment Lead Times (Transformer, Poles)

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

Wetland mitigation Undetermined until environmental analysis is complete. ***

D -Line Route could change Estimate based on one route. Upon funding CCN may identify alternate route. ****

Outages may not be available

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

Scope based on design assumptions which may change Varied impact on cost and schedule. ***

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

Bayou Meto Pump Station # 1 Rev.0B 11.18.11

8.0 TABLE OF ACRONYMS

ACSR Aluminum Conductor Steel Reinforced ACSS Aluminum Conductor Steel Supported ADEQ Arkansas Department of Environmental Quality AFUDC Allowance for Funds Used During Construction EES Entergy Control Area kV Kilo-Volt MCM (M) Thousand Circular Mils MVA Mega-Volt Amp(M) MW Mega-Watt

SOC System Operations Center SW Switch Station

TOC Transmission Operations Center SHPO Arkansas State Historic Preservation Office

SW Switch Station

TOC Transmission Operations Center

PT Potential Transformer CT Current Transformer CCVT Coupling Capacitor Voltage Transformer ASPEN Transmission System Modeling Program GOAB Gang Operated Air Break Switch LTC Limited Tap Changer – on Transformer windings RTU Remote Terminal Unit

9.0 ATTACHMENTS

A. Scope Summary Diagram / Area Map

B-1 One Line Drawings – 115kV/13.8kV Station

B-2 One Line Drawings – 13.8/4.16kV Station

C. Duration Schedule

D Environmental Review

Marshall, Valerie MVM

From: Hamm, Paul F MVM Sent: Thursday, April 18, 2013 3:50 PM To: Blackman, Estella C MVM Cc: Lloyd, James W MVM; Hamm, Paul F MVM; James, Tracy M MVM; Beech, Kenneth D MVM;

Marshall, Valerie MVM Subject: Rough Estimate for Power Supply to Pump Station (UNCLASSIFIED)

Classification: UNCLASSIFIED Caveats: NONE

Estella:

Reference your question about the $7 million origination, I looked around in the Bayou Meto documents and could not find anything. I found this email below, in which a range of $6 to $6.5 million is provided on 2 Oct 2012 by the General Manager of NLRED, Mike Russ. I believe that this email can be used to substantiate the cost to that point.

The $7 million figure is first noted in an email from 11 Jan 2013, which had an enclosure of the first draft of the J&A, and it quotes a $7 million cost. So, between 2 October and 11 January, the cost increased to $7 million. This is also the period when Mike Russ left NLRED. I seem to recall a telephonic conference call during which NLRED was quoting the $7 million, which surprised Gene Sullivan and us. I will ask Tracy to look for any notes from that call, or any other documents that support the estimated cost.

I hope this helps. It is my belief that the Mike Russ email below is going to be the only documented range of figures that gets us in the ballpark. Let us know your thoughts.

Paul

‐‐‐‐‐Original Message‐‐‐‐‐ From: James, Tracy M MVM Sent: Thursday, October 04, 2012 11:05 AM To: MRuss@northlittlerock.ar.gov; bm1300@aol.com; Edward Swaim Cc: pcathey@fisherarnold.com; smoore@fisherarnold.com; JBray@northlittlerock.ar.gov;

EHeinrichs@northlittlerock.ar.gov; jstephens@northlittlerock.ar.gov;

EHeinrichs@northlittlerock.ar.gov; KSnider@northlittlerock.ar.gov; Farmer, Jeffrey MVM; Hamm, Paul F MVM Subject: RE: Rough Estimate for Power Supply to Pump Station (UNCLASSIFIED)

Classification: UNCLASSIFIED Caveats: NONE

Mike ‐ I have talked with Jeff Farmer and he is satisfied with the modeling results presented by Fisher Arnold. I believe that you, the Bayou Meto Water Management District, and the Arkansas Natural Resources Commission need to meet and discuss your results and make some decisions. The Corps will be waiting to hear the results from this meeting and will be preparing to move forward as Federal funds become available.

Thanks, Tracy M. James Project Manager, Bayou Meto Project US Army Corps of Engineers, Memphis District

(901) 544‐0673

Enclosure 7 tracy.m.james@usace.army.mil

‐‐‐‐‐Original Message‐‐‐‐‐ From: MRuss@northlittlerock.ar.gov [mailto:MRuss@northlittlerock.ar.gov] Sent: Tuesday, October 02, 2012 2:41 PM To: bm1300@aol.com; James, Tracy M MVM Cc: pcathey@fisherarnold.com; smoore@fisherarnold.com; JBray@northlittlerock.ar.gov;

EHeinrichs@northlittlerock.ar.gov; jstephens@northlittlerock.ar.gov;

EHeinrichs@northlittlerock.ar.gov; KSnider@northlittlerock.ar.gov Subject: Rough Estimate for Power Supply to Pump Station

Gene and Tracy, I know that you need to have some idea of the costs so I will provide you a rough estimate if you promise to understand that this number is a ballpark number.

We are trying to obtain some better pricing information and complete engineering on the actual 69.5kv circuit which may take until late next week.

I also thought that the Corps wanted to get with Fisher Arnold to look in detail at the modeling work on starting these pumps to make sure that the Corps is in agreement with the results.

As of Monday this week this follow up meeting has not occurred.

Our rough estimate is $6 to $6.5 million at this time for the solution we discussed last call.

This includes all materials and labor with NLRED storing backup transformers at our Palm Street storage facility.

Please note that it will take almost one year to receive the transformers once the order is placed so this will be a critical step in being able to firm up an expected completion date.

Late next week, Thursday or Friday, we can schedule a conference call to review where we are and see if this approach is economically feasible for this project.

Jon Michael Russ, General Manager

ATTENTION: This email and any files transmitted with it are intended solely for the use of the individual or entity to whom they are addressed. Any unauthorized use, disclosure or

Enclosure 7 (con'td) distribution is prohibited. If you are not the intended recipient, please contact the sender by reply email and destroy all copies of the original message. The views or opinions presented in this email are solely those of the author and do not necessarily represent those of the City of North Little Rock. You are warned to check this email and any attachments for the presence of viruses. The City of North Little Rock accepts no liability for any damage caused by any virus transmitted by this email. ‐‐

Classification: UNCLASSIFIED Caveats: NONE

Classification: UNCLASSIFIED Caveats: NONE

Enclosure 7 (con'td)

ADDITIONAL DOCUMENTATION PROVIDED BY

NORTH LITTLE ROCK ELECTRIC DEPARTMENT (NLRED)

TO

U.S. ARMY CORPS OF ENGINEERS