2016 d onstruction tandards electrical distribution system · 2016-08-22 · 2016 design and...

2016 DESIGN AND CONSTRUCTION STANDARDS

ELECTRICAL DISTRIBUTION SYSTEM FORT WAINWRIGHT, FORT GREELY, & JOINT BASE ELMENDORF-RICHARDSON

714 FOURTH AVENUE, SUITE 100 PO BOX 74040FAIRBANKS, ALASKA 99701 FAIRBANKS ALASKA 99707

(907) 455-1500 www.doyonutilities.com

DESIGN AND CONSTRUCTION STANDARDS ELECTRICAL DISTRIBUTION SYSTEM

TABLE OF CONTENTS

2016 i Doyon Utilities, LLC

REVISION LOG ................................................................................................................................. iii

INTRODUCTION ............................................................................................................................... 1

SECTION 1 - STANDARDS AND CODES 2

1.1. DESIGN COMPLIANCE ............................................................................................... 2

SECTION 2 - DESIGN REQUIREMENTS 3

2.1. VOLTAGES ................................................................................................................. 3

2.2. LOADING CRITERIA .................................................................................................... 3

2.3. OVERLOAD/STRENGTH FACTORS AND CONSTRUCTION GRADE .............................. 4

2.4. CONDUCTOR LOADING LIMITS ................................................................................. 4

2.5. CLEARANCES ............................................................................................................. 4

2.6. TRANSFORMER SIZING .............................................................................................. 5

2.7. FACILITY SERVICE CONDUCTOR AND DISCONNECT SIZING ...................................... 7

SECTION 3 - CONSTRUCTION 8

3.1. OVERHEAD PRIMARY CONDUCTOR .......................................................................... 8

3.2. UNDERGROUND PRIMARY CONDUCTOR .................................................................. 8

3.3. SECONDARY CONDUCTOR ........................................................................................ 9

3.4. SPECIFIED CONDUCTOR LENGTHS ............................................................................ 9

3.5. POLES ........................................................................................................................ 9

3.6. POLE TOP ASSEMBLIES .............................................................................................. 9

3.7. INSULATORS ............................................................................................................ 10

3.8. GUYING ................................................................................................................... 10


TABLE OF CONTENTS

2016 ii Doyon Utilities, LLC

3.9. FOUNDATIONS & ANCHORS ................................................................................... 10

SECTION 4 - CONSTRUCTION SPECIFICATIONS 11

4.1. GENERAL ................................................................................................................. 11

4.2. OVERHEAD SPECIFICATIONS ................................................................................... 11

4.3. UNDERGROUND SPECIFICATIONS ........................................................................... 16

SECTION 5 - SAG TENSION CALCULATIONS 21

INDEX OF DRAWINGS / CONSTRUCTION UNITS 30


2016 iii Doyon Utilities, LLC

REVISION LOG

REFERENCE DESCRIPTION OF REVISION

Cover Sheet Added “FORT WAINWRIGHT AND FORT GREELY”

Cover Sheet Date “2015” changed to “2016”

All pages after Cover Sheet

Date in footer: “2015” changed to “2016”

All pages after Cover Sheet

Reformatted all sections

2.5.2. Clearances (Formally Design Requirements Section E)

Removed “we will”

2.5.3. Clearances (Formally Design Requirements Section E)

Removed “we will”

4.3.3.A. Backfilling (Formally Specifications C.3)

“In lieu of cleaning the trech, the Contractor may, at the Contractor’s option, place a 2 inch bed of clean sand or soil under the cable and 4 inches of clean soil above the cable.” changed to “If backfill material does not meet these requirements then a 2 inch bed of sand or clean soil under the cable and 4 inches of sand or clean soil above the cable shall be placed as shown on Drawing UR2.”

Drawing UR2 Revised Note 4 – “SAND BEDDING OR CLEAN SOIL IS REQUIRED.”


2016 1 Doyon Utilities, LLC

INTRODUCTION

Doyon Utilities is under contract to serve as the electrical power utility on JBER, Fort Greely and Fort Wainwright. The existing infrastructure at these three army posts is scheduled for replacement/upgrade and/or repair.

The purpose of this document is to establish the design criteria that will be used for line construction for all three of the army posts that Doyon Utilities serves.

Typical distribution electrical standards (primarily from United States Department of Agriculture, Rural Utility Systems (RUS)) have been used in compiling the units for this design manual. These standards have been used successfully on many Alaskan utility systems. These distribution standards will be utilized in conjunction with Design Criteria developed by Dryden & LaRue in response to the expected environmental conditions of the three posts and consideration of maximizing the useful life of the facilities.



SECTION 1 - STANDARDS AND CODES

1.1. DESIGN COMPLIANCE

1.1.1. The design will comply with the guideline and requirements of the following standards:

A. C2-2012 National Electric Safety Code (NESC)

B. American National Standards Institute (ANSI)

C. National Electrical Manufacturers Association (NEMA)



SECTION 2 - DESIGN REQUIREMENTS

2.1. VOLTAGES

2.1.1. The system voltages that will be utilized at the three posts are as follows:

A. JBER: 7.2/12.5 kV

B. Ft. Greely: 14.4/24.9 kV

C. Ft. Wainwright: 7.2/12.5 kV

2.1.2. All of these systems will be grounded wye systems for 3-phase circuits.

2.1.3. The existing system on JBER contains a mix of 7.2/12.5 kV Wye circuits and 7200V Delta circuits. The existing system on Ft. Greely is mainly 2400V Delta, with some 7200V Delta circuit on one feeder. As the circuits on these two posts are upgraded, they will be converted to the desired system voltage. The Wainwright system is already at the desired voltage and will not require conversion.

2.2. LOADING CRITERIA

2.2.1. Except where specific conditions dictate otherwise, the following loading criteria will be used for general design purposes:

2.2.2. NESC 250.B: Combined ice and wind district loading: Heavy Loading; 4 psf wind, ½ inch radial ice (57 lb/ft3), 0 F.

2.2.3. NESC 250.C: Extreme wind loading will typically not apply since we do not expect typical structures to be 60 feet above ground level, but as a conservative design approach, we will design for an extreme wind of 25.6 psf (100 mph) at 40 F, with no overload factors. We will use this extreme wind criterion at all three posts, including Ft. Greely, where high winds are most frequently encountered.

2.2.4. NESC 250.D: Extreme ice with concurrent wind loading does not apply since we do not expect typical poles to be 60 feet above ground level; for special cases where structures are 60 feet or taller, we will apply the NESC minimum extreme ice and wind loading in accordance with NESC 250.D. At Ft. Greely only, we have included a design condition of ¾” of radial ice, 0 F with a 4 psf wind, no overload factors, to account for extreme conditions encountered there.



2.2.5. Other Extreme Loading Criteria: We will design for an extreme low temperature of -40 F at Ft. Greely and Ft. Wainwright. At Ft. Wainwright, we have included an extreme ice condition of ¾” radial ice at 0 F, without wind.

2.3. OVERLOAD/STRENGTH FACTORS AND CONSTRUCTION GRADE

2.3.1. In order to maximize the life of the new facilities, new distribution line will be designed to meet NESC Grade “B” construction to the greatest extent possible. The following table indicates the overload and strength factors for NESC Grade “B” construction.

Overload Capacity Factor / Strength Factor Wire Longitudinal Equipment Wind Tension Vertical Non-Deadend Deadend

Hardware, Anchors 2.5/1.0 1.65/1.0 1.5/1.0 1.1/1.0 1.65/1.0

Guys 2.5/0.9 1.65/0.9 1.5/0.9 1.1/0.9 1.65/0.9

Wood 4.0/1.0 2.0/1.0 2.2/1.0 1.33/1.0 2.0/1.0

Steel 2.5/1.0 1.65/1.0 1.5/1.0 1.1/1.0 1.65/1.0

2.4. CONDUCTOR LOADING LIMITS

2.4.1. Conductor loading limits for all conductors will be as follows:

A. NESC Heavy Condition (4 psf wind, ½ inch radial ice 0 F) = 50% initial

B. Unloaded (0 F, no wind, no ice) = 33% Initial & 25% Final

2.4.2. In addition, a tension limiting vibration control condition will be selected based on conductor type to eliminate the requirement for vibration dampers except for special cases and unusually long spans.

2.5. CLEARANCES

2.5.1. Clearances to ground and other installations will meet or exceed the requirements of the 2007 NESC. Typical NESC required clearances are as shown in the following table:



Clearance Item Minimum Clearance Sag Criteria

7.2/12.5 kV and 14.4/24.9 kV Vertical Clearances (NESC)

Over Ground and Roads 18.5’ 32°F, 1/2" Ice, No Wind, Final Sag OR 120°F, No Ice, No Wind, Final Sag*

Over Communication Cables (carried on other support structures) 5.0’ 32°F, 1/2" Ice, No Wind, Final Sag OR 120°F,

No Ice, No Wind, Final Sag* Over Open Supply Conductors (carried on other structures, up to 22 kV to ground)

2.0’ 120°F, No Ice, No Wind, Final Sag*

Over Railroad Tracks 26.5’ 60°F, No Ice, No Wind, Final Sag 7.2/12.5 kV and 14.4/24.9 kV Horizontal Clearances (NESC)

From Buildings (No wind displacement) 5.0’ 60°F, No Ice, No Wind, Final Sag

From Buildings (With wind displacement) 4.5’ 60°F, No Ice, 6psf Wind, Final Sag

* Whichever criteria produces the greatest sag

2.5.2. In addition to the NESC criteria, design for 25’ clearance over road at the same conditions as above (32°F, 1/2" Ice, No Wind, Final Sag OR 120°F, No Ice, No Wind, Final Sag) to accommodate military vehicles with whip antennae up to 20’ in height.

2.5.3. Where overhead facilities are located within ADOT&PF right-of-way, design for 20’ of clearance in accordance with ADOT&PF permitting requirements.

2.6. TRANSFORMER SIZING

2.6.1. New transformers should be sized at 50% of the sum of the National Electrical Code (NEC) calculated service loads, or connected loads for all buildings and services connected to the transformer. For single phase loads served by a three phase transformer, the largest of the single phase services should be treated as connected to all three phases of the transformer, i.e. A transformer with a 400 Amp 3 –phase service, 100 amp single phase service, and 50 Amp single phase service should be sized as if 500 Amps of load are connected to all three phases.

2.6.2. For building services where there is no load calculation or connected load information, the main service breaker or fuse rating shall be used as the connected load amps. For locations where main service disconnect is not located on the outside of the building, methodology for sizing an external disconnect shall be as indicated in the section on Service Sizing (see below).



2.6.3. For replacement of existing transformers, transformer should match size of existing transformer unless buildings and loads being served by the existing transformer are changing, or the existing transformer is grossly under or over sized. A review of the transformer size should be done as noted for new transformers. Non-standard size existing transformers being replaced shall have replacement transformers sized as noted for new transformers.

2.6.4. In all cases, transformer sizes determined as noted above shall be rounded up to the next standard size when applicable.

2.6.5. Standard transformer sizes for Doyon Utilities include:

A. Single-Phase Overhead [kVA]: 15, 25, 37.5, 50, 75, 100

B. Single-Phase Padmount [kVA]: 25, 50, 75

C. Three-Phase Padmount [kVA]: 75, 112.5, 150, 225, 300, 500, 750

2.6.6. At a minimum, transformers should be specified or provided with the following accessories in addition to the factory standard items:

A. Overhead Transformers: Dual Bushing NLTC +/- 2.5% and +/-5% Provide nameplate and dimensional drawing and factory test data with the shipped unit

B. Padmount Transformers: Dual Bushing 225kVA and larger supply secondary spades inplace of mechanical set screw bars 500kVA and larger supply secondary supports Dual voltage as required depending on installation location Bayonet and current limiting fusing NLTC +/-2.5% and +/-5% Bushing inserts Thermometer(3ph) Oil Level gauge(3ph) Pressure gauge(3ph) Seismic anchoring provisions Provide nameplate and dimensional drawing and factory test data with the shipped unit



2.7. FACILITY SERVICE CONDUCTOR AND DISCONNECT SIZING

2.7.1. In most instances, facilities and loads served will have an external main disconnect, with a fuse or main breaker rating. The secondary service conductors from the transformer to the disconnect shall be sized with a minimum ampacity of 80% of the main breaker or fuse ampere rating.

2.7.2. For facilities where main service disconnect is not present or is located inside the building, an assumed service disconnect size should be used for both transformer sizing and service conductor sizing. This service disconnect should be sized using one of two options. The first and preferred option is that the service disconnect is sized based upon the NEC building service calculation. However, in most locations, this calculation will not be available.

2.7.3. The second and likely option is to size the service disconnect based upon the NEC ampacity of the main feeder conductors. Note that this is the building main feeder conductors, not the utility side service conductors, i.e. for an overhead service, this is the conductors within the weatherhead and mast, not the triplex/quadplex that runs from the transformer to the weatherhead. (In some cases these main feeder conductors and utility service conductors may be one and the same). This service disconnect size for the main feeder conductors shall be sized for the ampacity of the main feeder conductors per the NEC 240.4. The ampacity of the feeder conductors shall be per NEC 110.14(C) and NEC Table 310.16. For example, if the main building feeder conductors are #2 CU with XHHW insulation, they have a listed ampacity of 115 Amps, but according to NEC 240.4 these may be protected by the next standard fuse/breaker size: a 125 Amp breaker or fuse. Therefore, the assumed service size will be 125 Amps.

2.7.4. In locations where exterior building disconnect is not present on an existing building that new service is being provided, coordinate with the Doyon Project Manager; they may desire that a new exterior building disconnect and meterbase are installed as a part of the utility upgrade project.



SECTION 3 - CONSTRUCTION

3.1. OVERHEAD PRIMARY CONDUCTOR

3.1.1. ACSR conductors have been selected for each of the posts based upon expected feeder loads as well as matching recent system upgrades.

A. JBER: Main feeders: 4/0 ACSR, 6/1 stranding, codeword “Penguin” Taps: #2 ACSR, 7/1 stranding, codeword “Sparate”

B. Ft. Greely: Feeder 9 main feeder: 4/0 ACSR, 6/1 stranding, codeword “Penguin” Other feeders and taps: #2 ACSR, 7/1 stranding, codeword “Sparate”

C. Ft. Wainwright: Main feeders: 336 kcmil ACSR, 18/1 stranding, codeword “Merlin” Taps: 1/0 ACSR, 6/1 stranding, codeword “Raven”

3.1.2. Sag-tension calculation tables have been included in SECTION 5 for each of these conductors and their expected ruling spans.

3.2. UNDERGROUND PRIMARY CONDUCTOR

3.2.1. The following conductors are standard conductor sizes used for system upgrades at the three posts, with 125% insulation levels selected based upon the operating voltage of the post (15kV cable at JBER and Ft. Wainwright, 25kV Cable at Ft. Greely)

A. Main feeders: 500MCM CU Tape Shield*, 4/0 CU Tape Shield*

B. Taps and lower ampacity feeders: #1/0 AL Concentric Full Neutral

*Provide 600V insulated separate neutral conductor for Tape Shield installations

3.2.2. Additional conductor sizes may be utilized for special ampacity needs; existing underground installations may not be standard conductor sizes if recently installed and in good condition at time of feeder upgrade.

3.2.3. Underground conductor shall be installed in conduit for all installations; direct buried conductor is not allowed. For installations beneath roadways, driveways and parking lots, conduit shall be HDPE, rigid steel conduit, or Schedule 80 PVC. Schedule 40 PVC shall not be used for driveway, parking lot and roadway crossings.



3.3. SECONDARY CONDUCTOR

3.3.1. Standard secondary conductor sizes for Doyon Utilities are:

A. Single-Phase (Triplex) Overhead: #2, #1/0, #4/0

B. Three-Phase (Quadplex) Overhead: #1/0, #4/0, 350 kcmil

C. Single-Phase (Triplex) Underground: #2, #1/0, #4/0, #350 kcmil

D. Three-Phase (Quadplex) Underground: #1/0, #4/0, 350 kcmil, 500 kcmil, 350 kcmil CU, 500 kcmil CU, and 750 kcmil CU

Note: all secondary standard conductor sizes are aluminum unless noted as copper (CU) above.

3.4. SPECIFIED CONDUCTOR LENGTHS

3.4.1. Overhead conductor lengths listed on staking sheets are to be point to point straight line distance between poles, rounded to the nearest foot.

3.4.2. Underground conductor lengths listed on staking sheets are to be the conduit distance between the two pieces of equipment with additional make-up lengths at each end. The recommended make-up lengths for underground conductor are 15’ at pad mounted equipment, and the pole length at risers. (i.e a riser on a 45/3 pole would have a make-up length of 45’). These conductor lengths should be rounded up to the nearest 5’.

3.5. POLES

3.5.1. Wood poles will be used throughout the post distribution system. Typical wood pole sizes will be 45’ for single circuit lines, and 50’ poles for double circuit lines. Taller or shorter pole heights will be used as required by terrain conditions and other special considerations. Class 3 poles will be used for tangent and angle structures on single circuit line, with Class 2 poles utilized at deadends. Class 2 poles will be utilized for double circuit tangent and angle poles, while Class 1 poles will be utilized for poles that have double circuit deadends. These values are based upon 200 foot spans for Merlin conductor and 250 foot spans for other conductors, and also do not include provisions for communication underbuild. Longer spans and lines with communications underbuild will be individually considered and pole classes will be selected based upon loadings.

3.6. POLE TOP ASSEMBLIES

3.6.1. Wood crossarm assemblies will be used for tangent and small to medium angle assemblies on three phase circuits. These assemblies will typically be 4-



conductor flat configuration with the neutral mounted up on the crossarms with the phase conductors. Single phase circuits will be a combination of crossarm and vertical construction assemblies. Deadends will typically utilize crossarm construction horizontal deadends for #2 conductor, and Hughes arm assemblies for conductors larger than #2. Typical pole top assembly units can be found in the INDEX OF DRAWINGS / CONSTRUCTION UNITS.

3.7. INSULATORS

3.7.1. Insulators for the distribution system will consist of porcelain pin insulators for tangent and small angle assemblies, and polymer suspension insulators for deadends and large angles. Insulators will be rated 15kV for the JBER and Ft. Wainwright systems, and rated 25 kV for the Ft. Greely system.

3.8. GUYING

3.8.1. Doyon has selected 3/8” EHS as standard downguy and span guy stranding at all three posts. 3/8” EHS has rated strength of 15,400 lbs. Guying hardware will be selected to match the strength of the downguy strand; 15,000 lb rated hardware will be utilized on single downguy and span guy units, and 30,000 lb rated hardware will be utilized for hardware connected to double guy strands. We also will include a light duty unit with a guy hook pole attachment (8,500 lbs rating) for use with secondary, small angles, and other light loads. For deadend poles, assemblies using multiple downguys will be required. We have calculated grade “B” construction will typically require 3 downguys for 336 and #4/0 conductor 3-phase deadends, and 2 downguys for #1/0 and #2 conductor 3-phase deadend assemblies. Typical downguy assemblies can be found in the INDEX OF DRAWINGS / CONSTRUCTION UNITS.

3.9. FOUNDATIONS & ANCHORS

3.9.1. Poles will be direct embedded where soil conditions allow. Imported backfill will be used as needed if poor backfill materials are encountered during installation. For areas where soil conditions are not suitable for direct embedment, steel H-pile or pipe pile foundations will be utilized.

3.9.2. Anchors will be screw anchors wherever soil conditions allow installation of those assemblies. At locations where gravels, cobles and rocks are expected and soil conditions are good, plate anchors will be utilized that have equivalent holding capacity. Typical anchor assemblies can be found in the INDEX OF DRAWINGS / CONSTRUCTION UNITS.



SECTION 4 - CONSTRUCTION SPECIFICATIONS

4.1. GENERAL

4.1.1. All construction work shall be done in a thorough and workman-like manner in accordance with the Staking Sheets, Plans and Specification, and Construction Drawings. All work areas shall be left clean of any excess materials and garbage.

4.1.2. The C2-2012 Edition of the National Electric Safety Code (NESC) shall be followed except where local regulations are more stringent, in which case local regulations shall govern. The design was performed per C2-2012 NESC, if construction is delayed and occurs under a later code, the design must be reviewed for the later code prior to construction.

4.1.3. Some of the drawings and specifications are from RUS bulletins 1728F-804 “Specifications and Drawings for 12.47/7.2 kV Construction” and 1728F-803 “Specifications and Drawings for 24.9/14/4kV Construction” and 1728F-806 “Specifications and Drawings for Underground Electric Distribution Construction”.

4.2. OVERHEAD SPECIFICATIONS

4.2.1. Distributing Poles

A. In distributing the poles, large, choice, close-grained poles shall be used for transformers, deadend, angle, and corner poles.

4.2.2. Pole Setting

A. The minimum depth for setting poles shall be as follows:

Length of Pole Setting in Soil Setting in all Solid Rock (feet) (feet) (feet)

20 4.0 3.0 25 5.0 3.5 30 5.5 3.5 35 6.0 4.0 40 6.0 4.0 45 6.5 4.5 50 7.0 4.5 55 7.5 5.0 60 8.0 5.0



B. “Setting in Soil” specifications shall apply: Where poles are to be set in soil. Where there is a layer of soil of more than two (2) feet in depth over solid rock. Where the hole in solid rock is not substantially vertical or the diameter of the hole at the surface of the rock exceeds approximately twice the diameter of the pole at the same level.

C. “Setting in All Solid Rock” specifications shall apply where poles are to be set in solid rock and where the hole is substantially vertical, approximately uniform in diameter and large enough to permit the use of tamping bars the full depth of the hole.

D. Where there is a layer of soil two (2) feet or less in depth over solid rock, the depth of the hole shall be the depth of the soil in addition to the depth specified under “Setting in All Solid Rock” provided, however, that such depth shall not exceed the depth specified under “Setting in Soil.”

E. On sloping ground, the depth of the hole always shall be measured from the low side of the hole.

F. Poles shall be set so that alternate crossarm gains face in opposite directions, except at terminals and deadends where the gains of the last two (2) poles shall be on the side facing the terminal or deadend. On unusually long spans, the poles shall be set so that the crossarm comes on the side of the pole away from the long span. Where pole top pins are used, they shall be on the opposite side of the pole from the gain, with the flat side against the pole.

G. Poles shall be set in alignment and plumb except at corners, terminals, angles, junctions, or other points of strain, where they shall be set and raked against the strains so that the conductors shall be in line.

H. Poles shall be raked against the conductor strain not less than one (1) inch for each ten (10) feet of pole length nor more than two (2) inches for each ten (10) feet of pole length after conductors are installed at the required tension.

I. Pole backfill shall be thoroughly tamped in full depth. Excess soil shall be banked around the pole to a nominal depth of 2’ and sloped to provide drainage away from the pole.

J. Poles which have been in storage for more than 1 year from the date of treatment shall be ground line treated when installed.

4.2.3. Grading of Line and Bolts

A. There shall be no upstrain on pin-type insulators in grading the line each way to lower poles when using high poles to clear obstacles such as buildings, foreign wire crossings, railroads, etc.

B.



C. All bolts employed for the mounting of hardware items on poles shall be long enough to fully engage the nut (including locknut, where applicable) but shall not extend more than 2 in. beyond the nut after the nut is tightened. The ends of bolts shall not be cut.

4.2.4. Hardware

A. All pole hardware shall be from RUS’s current approved material list. All bolts, nuts, washers, and other mounting hardware shall be hot-dipped galvanized.

4.2.5. Guys and Anchors

A. Guys shall be placed before the conductors are strung and shall be attached to the pole.

B. All anchors and rods shall be in line with the strain and shall be so installed that approximately six (6) inches of the rod remain out of the ground. In cultivated fields or other locations, as deemed necessary, the projection of the anchor rod above earth may be increased to a maximum of twelve (12) inches to prevent burial of the rod eye. The backfill of all anchor holes must be thoroughly tamped the full depth.

C. Power screw anchors shall be installed in accordance with manufacturer’s instructions to provide the designated holding power listed on the assembly drawings. Utilize a torque measuring method (either shear pins or a torque indicator attachment) along with the manufacturer’s installed torque vs. holding capacity relationship data and install anchors to required torque in order to achieve the designated holding capacity.

D. All guys shall be equipped with guy markers with reflective tape/material providing high visibility.

4.2.6. Locknuts

A. A locknut shall be installed with each nut, eyenut or other fastener on all bolts or threaded hardware such as insulator pins, upset bolts, double arming bolts, etc.

4.2.7. Conductors

A. Conductors must be handled with care. Conductors shall not be tramped on or run over by vehicles. Each reel shall be examined and the wire shall be inspected for cuts, kinks, or other damaged. Damaged portions shall be cut out and the conductors spliced. The conductors shall be pulled over suitable rollers or stringing blocks properly mounted on pole or crossarm if necessary to prevent binding while stringing.

B. The neutral conductor shall be maintained on the road side of the pole whenever practicable.



C. With pin-type insulators the conductors shall be tied in the top groove of the insulator on tangent poles and on the side of the insulator away from the strain at angles. Pin-type insulators shall be tight on the pins and on tangent construction the top groove must be in line with the conductors after tying in.

D. All conductors shall be cleaned thoroughly by wire brushing before splicing or the installation of a connector or clamp. A suitable inhibitor shall be used before splicing or applying connectors over aluminum conductor.

4.2.8. Splices and Deadends

A. There shall be not more than one (1) splice per conductor in any span and splicing sleeves shall be located at least ten (10) feet from the conductor support. No splices shall be located in Grade B crossing spans and preferably not in the adjacent spans. Splices shall be installed in accordance with the manufacturer's recommendations.

4.2.9. Taps and Jumpers

A. Jumpers and other leads shall be bare or covered copper conductor. Jumpers and other leads connected to line conductors shall have sufficient slack to allow free movement of the conductors. Where slack is not shown on the Construction Drawings it will be provided by at least two (2) bends in a vertical plane, or one (1) in a horizontal plane, or the equivalent. In areas where aeolian vibration occurs, special measures to minimize the effects of jumper breaks shall be used as specified.

B. Leads on equipment such as transformers, reclosers, etc. shall be minimum #4 Cu. Utilize hot-line clamps with stirrups for connection of equipment leads to line as indicated on the assembly details.

C. All primary jumpers shall consist of conductors matching or exceeding ampacity of the main line conductor and be insulated for bird protection where required. AMPACT or equivalent connectors suitable for bi-metallic connections shall be used for jumper connections.

4.2.10. Hot-Line Clamps and Connectors

A. Connectors and hot-line clamps suitable for the purpose shall be installed as shown on Guide Drawings. Stirrups shall be used with all hot-line clamp installations. On all hot-line clamp installations, the clamp and jumper shall be so installed so that they are permanently bonded to the load side of the line, allowing the jumper to be de-energized when the clamp is disconnected. This applies in all cases, even where the line layout is such that the tap line is in actuality the main back to the power source.



4.2.11. Conductor Ties

A. Ties shall be in accordance with Construction Drawings. Hot-line ties shall not be used at Grade “B” crossings. Ties shall be a pre-formed type.

4.2.12. Sagging of Power Conductors

A. Conductors shall be sagged in accordance with the provided stringing tables. However, under no circumstances will a decrease in the specified sag be allowed. All conductors shall be sagged evenly. Stringing of conductors shall be done using travelers of proper diameter for the conductor selected. The air temperature at the time and place of sagging shall be determined by a certified etched glass thermometer. After bringing conductor to proper sag, deadends are to be secure within 2 hours. Wire must be tied to insulators within 48 hours.

4.2.13. Secondary and Service Drops

A. Secondary conductors may be covered wires or multi-conductor service cable. The conductors shall be sagged in accordance with manufacturers’ recommendations. Open wire secondary shall not be utilized for new installations.

B. Secondaries and service drops shall be so installed as not to obstruct climbing space. There shall not be more than one (1) splice per conductor in any span, and splicing sleeves shall be located at least ten (10) feet from the conductors support. Where the same covered conductors or service cables are to be used for the secondary and service drop, they may be installed in one (1) continuous run.

4.2.14. Grounds

A. Ground rods shall be driven full length in undisturbed soil in accordance with the Construction Drawings. The top shall be at least twelve (12) inches below the surface of the earth. The ground wire shall be attached to the rod with a clamp and secured to the pole with staples. The staples on the ground wire shall be spaced two (2) feet apart except for a distance of eight (8) feet above the ground and eight (8) feet down from the top of the pole where they shall be six (6) inches apart.

B. All equipment shall have at least two (2) connections from the frame, case or tank to the multi-grounded neutral conductor.

C. The equipment ground, neutral wires, and lightning-protective equipment shall be interconnected and attached to a common ground wire.



4.2.15. Clearing of Right-Of-Way

A. The right-of-way shall be prepared by removing trees, clearing underbrush, and trimming trees so that the right-of-way is cleared close to the ground at the width specified. Low growing shrubs which will not interfere with the operation or maintenance of the line shall be left undisturbed if so directed by the Owner. Slash may be chipped and blown on the right-of-way unless strictly prohibited by Doyon Utilities, federal, state or local laws. Trees fronting each side of the right-of-way shall be trimmed symmetrically unless otherwise specified. Dead trees beyond the right-of-way which would strike the line in falling shall be removed. Leaning trees beyond the right-of-way, which would strike the line in falling and which would require topping if not removed, shall either be removed or topped.

4.3. UNDERGROUND SPECIFICATIONS

4.3.1. Storage of Material and Equipment

A. It is the responsibility of the contractor to ensure that all material and equipment to be used in construction must be stored so as to be protected from deteriorating effects of the elements. If outdoor storage cannot be avoided, the material and equipment must be stacked on supports well above the ground line and protected from the elements as appropriate, and with due regard to public safety.

4.3.2. Trenching

A. All excavations shall be in compliance with Federal and State OSHA requirements.

B. Trench depth shall be per the trench detail drawing. Minimum burial depth for primary shall be 48”; for secondary and streetlighting minimum burial depth shall be 30” except beneath roadways, where 48” shall apply. These depths may be reduced if concrete encasement or other supplemental protection is provided. The bottom of trench shall be free of any sharp rocks or material that may cause damage to cables. At no point shall the cables suspend over a hole or gap in the trench, such voids shall be filled with appropriate material.

C. It is the responsibility of the contractor to ensure that all trenching depths specified is minimum as measured from the final grade to the top surface of the cable. The routing must be as shown on the staking sheets and plans and specifications unless conditions encountered are such that changes are necessary to accomplish the work. Trenching in rock may be encountered, if the trench alignment is to be altered from the proposed trench alignment the Owner shall be notified to make a decision on what course of action will be taken. The trench widths specified is minimum and should be increased as necessary to obtain the required depths in loose soils.



D. Care shall be exercised to minimize the likelihood of water flow since this may cause trench damage and reduction in trench depth. If this occurs, the trench must be cleared to the specified depth before installing the cable.

E. Construction shall be arranged so that trenches may be left open for the shortest practical time to avoid creating a hazard to the public and to minimize the likelihood of collapse of the trench due to other construction activity, rain, accumulation of water in the trench, etc.

4.3.3. Backfilling

A. It is the responsibility of the contractor to ensure that the first 6 inches of trench backfill shall be free from rock, gravel or other material which might damage the cable jacket. If backfill material does not meet these requirements then a 2 inch bed of sand or clean soil under the cable and 4 inches of clean soil above the cable shall be placed as shown on Drawing UR2. Cleaned soil backfill when used shall contain no solid material larger than l inch and be non-frost susceptible. This soil layer must be carefully compacted so that the cable will not be damaged.

B. Backfilling must be completed in such a manner that voids will be eliminated. Excess soil must be piled on top and must be well tamped. All rock and debris must be removed from the site, and any damage to the premises repaired immediately.

C. Pieces of scrap cable or other material remaining after installation must not be buried in the trench as a means of disposal.

D. Backfilled material shall be compacted for all road crossings, landscaped areas, and where specified.

4.3.4. Conduit

A. It is the responsibility of the contractor to ensure that all exposed ends of conduit must be plugged during construction to prevent the entrance of foreign matter and moisture into the conduit. Burrs or sharp projections which might injure the cable must be removed. Riser shield or conduit must extend at least 18 inches below grade at all riser poles. If full round conduit is used as a riser shield, a bushing must be installed on the lower end to prevent damage to the cable.

4.3.5. Underground Cable

A. Handling of Cable It is the responsibility of the contractor to ensure that the cable shall be handled carefully at all times to avoid damage, and shall not be dragged across the ground, fences or sharp projections. Care shall be exercised to



avoid excessive bending of the cable. The contractor shall ensure that the ends of the cable be sealed at all times against moisture with suitable end caps. Where it is necessary to cut the cable, the ends will be terminated or sealed immediately after the cutting operation.

B. Minimum Bending Radius of Cable It is the responsibility of the contractor to ensure that the minimum bending radius of primary cable is 12 times the overall diameter of the cable or per manufacturer’s recommendations, which ever is larger. The minimum bending radius of secondary and service cable is six times the overall diameter of the cable. In all cases the minimum radius specified is measured to the surface of the cable on the inside of the bend. Cable bends must not be made within 6 inches of a cable terminal base.

C. Installation in Conduit or Duct Where cable must be pulled through conduit or duct, the operation shall be performed in such a way that the cable will not be damaged from strain or dragging. The cable shall be lubricated with a suitable cable lubricant prior to pulling into conduit or duct. In placing primary cables, the stress applied while pulling into ducts or during other pulling operations shall not exceed the least of the following:

1. Where a pulling eye is attached to the conductor, the maximum pulling strain in pounds shall not exceed .006 times the circular mil area for aluminum or .008 times the circular mil area for copper.

2. Where a basket grip is placed over the cable, the pulling strain shall not exceed the lesser of: (1) that calculated in above; or (2) 1000 pounds. The cable under the cable grip and 1.0 foot preceding it shall be severed and discarded after the pulling operation.

3. Pulling tension shall be monitored at all times. 4. In no case shall the maximum pulling tension exceed that

recommended by the specific cable manufacturer.5. At bends the maximum sidewall pressure recommended by

the cable manufacturer shall not be exceeded.

D. Tagging of Cables at Termination Points Cables shall be tagged and identified at all accessible locations as the cables are laid. The identification must be of a permanent type, such as that done on plastic or corrosion resistant metal tags. The tag must be securely attached to the cable. Paper or cloth tags are not acceptable.

E. Splices It is the responsibility of the contractor to ensure that cable splices must be of the premolded rubber, heat-shrink, or cold-shrink type, of the correct voltage rating and must be installed in accordance with the splice



manufacturer's instructions. Splices that depend solely on tape for a moisture barrier must not be used. Not more than one splice may be permitted for each 2000 feet of cable installed unless authorized by the Owner. No bends may be permitted within 12 inches of the ends of a splice. The cable or circuit numbers and the exact location of all splices must be noted on the staking sheets (as built).

F. Primary Cable Termination and Stress Cones It is the responsibility of the contractor to ensure that prefabricated stress cones or terminations must be installed in accordance with the manufacturer's instructions at all primary cable terminals. They must be suitable for the size and type of cable that they are used with and for the environment in which they will operate. Any indication of misfit, such as a loose or exceptionally tight fit, must be called to the Owner's attention. The outer conductive surface of the termination must be bonded to the system neutral. A heat-shrink or cold-shrink sleeve must be installed to seal between the body of the termination and the cable jacket.

G. Special Precautions for Cable Splices and Terminations It is the responsibility of the contractor to ensure that a portable covering or shelter must be available for use when splices or terminations are being prepared and when prefabricated terminations are being switched. The shelter must be used as necessary to keep rain, snow and windblown dust off the insulating surfaces of these devices. Since cleanliness is essential in the preparation and installation of primary cable fittings, care shall be exercised to prevent the transfer of conducting particles from the hands to insulating surfaces. Mating surfaces must be wiped with a solvent such as denatured alcohol to remove any possible accumulation of dirt, moisture or other conducting materials. A silicone grease or similar lubricant should be applied afterwards in accordance with the manufacturer's recommendations. Whenever prefabricated cable devices are opened, the unenergized mating surfaces must be lubricated with silicone grease before the fittings are reconnected.

4.3.6. Secondary and Service Connections

A. It is the responsibility of the contractor to ensure that a suitable inhibiting compound must be used with all secondary and service connections.

B. All secondary cable connections located below grade or in secondary pedestals must be made with pre-insulated secondary connector blocks. Diving bells with open terminals, insulating boots or moisture barriers that depend solely on tape are not acceptable.

C. All transformer secondary phase terminal connections must be completely insulated. If the secondary phase terminals are threaded studs, the connection



must be made with a pre-insulated secondary transformer connection block. If the transformer secondary phase terminals are insulated cable leads, connection must be made with a pre-insulated secondary connector block or with a secondary prefabricated splice when the transformer leads continue directly to the service.

D. If a transformer is so large that it must have secondary spades, the spades must be taped or otherwise insulated. Boots used for insulation must be taped so that they cannot be readily slipped off.

E. Secondary connections to terminals of pole-mounted transformers must be made so that moisture cannot get inside the cable insulation. This may be accomplished by covering the terminals and bare conductor ends with an appropriate moisture sealant or providing a drip loop.

F. The secondary connections and insulation must have accommodations for all future and existing services as shown on the plans and specifications.

4.3.7. Grounding

A. It is the responsibility of the contractor to ensure that all neutral conductors, grounding electrodes, and groundable parts of equipment shall be interconnected. All interconnections shall be made as shown on the construction drawings. A copper-clad or galvanized steel ground rod with minimum length of 8 feet shall be installed at all equipment locations as shown in the construction drawings and at all cable splices and taps.

B. All pad-mounted equipment enclosures, including transformers, shall be grounded in such a manner that two separate grounding paths exist between the enclosure and the grounding rod(s).



SECTION 5 - SAG TENSION CALCULATIONS

ALUMINUM COMPANY OF AMERICA SAG AND TENSION DATA

Doyon Utilities FRA, FWA, FGA Medium Conductor (#2 ACSR Sparate)

Conductor SPARATE # 2 AWG 7/ 1 Stranding ACSR Area= .0654 Sq. in Dia= .325 in Wt= .107 lb/ft RTS= 3640 lb Data from Chart No. 1-670 English Units Using Exact Catenary Equations

Span= 150.0 feet NESC Heavy Load Zone Creep is NOT a Factor Rolled Rod Design Points Final Initial Temp Ice Wind K Weight Sag Tension RTS Sag Tension RTS F in psf lb/ft lb/ft ft lb % ft lb % 0. .75 4.00 .00 1.265 2.53 1407. 38.7 2.53 1407. 38.7 0. .50 4.00 .30 1.061 2.30 1298. 35.7 2.26 1321. 36.3* 32. .50 .00 .00 .620 1.95 894. 24.6 1.75 996. 27.4 -40. .00 .00 .00 .107 .27 1112. 30.5 .25 1180. 32.4 -20. .00 .00 .00 .107 .32 952. 26.2 .28 1073. 29.5 0. .00 .00 .00 .107 .38 794. 21.8 .31 959. 26.4 30. .00 .00 .00 .107 .53 565. 15.5 .39 775. 21.3 60. .00 .00 .00 .107 .83 362. 9.9 .52 575. 15.8 90. .00 .00 .00 .107 1.32 228. 6.3 .80 378. 10.4 120. .00 .00 .00 .107 1.59 189. 5.2 1.30 232. 6.4 167. .00 .00 .00 .107 2.04 148. 4.1 1.93 156. 4.3 212. .00 .00 .00 .107 2.46 123. 3.4 2.35 128. 3.5 * Design Condition

Span= 200.0 feet NESC Heavy Load Zone Creep is NOT a Factor Rolled Rod Design Points Final Initial Temp Ice Wind K Weight Sag Tension RTS Sag Tension RTS F in psf lb/ft lb/ft ft lb % ft lb % 0. .75 4.00 .00 1.265 4.40 1440. 39.6 4.40 1440. 39.6 0. .50 4.00 .30 1.061 4.10 1297. 35.6 4.02 1321. 36.3* 32. .50 .00 .00 .620 3.65 849. 23.3 3.33 932. 25.6 -40. .00 .00 .00 .107 .74 728. 20.0 .60 899. 24.7 -20. .00 .00 .00 .107 .92 582. 16.0 .69 781. 21.5 0. .00 .00 .00 .107 1.19 451. 12.4 .81 659. 18.1 30. .00 .00 .00 .107 1.77 303. 8.3 1.13 475. 13.1 60. .00 .00 .00 .107 2.45 218. 6.0 1.66 322. 8.8 90. .00 .00 .00 .107 2.92 183. 5.0 2.35 228. 6.3 120. .00 .00 .00 .107 3.27 164. 4.5 3.02 177. 4.9 167. .00 .00 .00 .107 3.79 142. 3.9 3.65 147. 4.0 212. .00 .00 .00 .107 4.25 126. 3.5 4.12 130. 3.6 * Design Condition�

222016 Doyon Utilities, LLC

Span= 250.0 feet NESC Heavy Load Zone Creep is NOT a Factor Rolled Rod Design Points Final Initial Temp Ice Wind K Weight Sag Tension RTS Sag Tension RTS F in psf lb/ft lb/ft ft lb % ft lb % 0. .75 4.00 .00 1.265 6.76 1466. 40.3 6.76 1466. 40.3 0. .50 4.00 .30 1.061 6.40 1299. 35.7 6.29 1321. 36.3* 32. .50 .00 .00 .620 5.90 823. 22.6 5.48 886. 24.3 -40. .00 .00 .00 .107 2.29 366. 10.0 1.56 535. 14.7 -20. .00 .00 .00 .107 2.81 298. 8.2 1.93 433. 11.9 0. .00 .00 .00 .107 3.34 250. 6.9 2.39 350. 9.6 30. .00 .00 .00 .107 4.09 204. 5.6 3.17 264. 7.3 60. .00 .00 .00 .107 4.77 175. 4.8 3.94 212. 5.8 90. .00 .00 .00 .107 5.15 163. 4.5 4.65 180. 4.9 120. .00 .00 .00 .107 5.51 152. 4.2 5.30 158. 4.3 167. .00 .00 .00 .107 6.05 138. 3.8 5.90 142. 3.9 212. .00 .00 .00 .107 6.54 128. 3.5 6.39 131. 3.6 * Design Condition Certain information such as the data, opinions or recommendations set forth herein or given by AFL representatives, is intended as a general guide only. Each installation of overhead electrical conductor, underground electrical conductor, and/or conductor accessories involves special conditions creating problems that require individual solutions and, therefore, the recipient of this information has the sole responsibility in connection with the use of the information. AFL does not assume any liability in connection with such information.�

23 Doyon Utilities, LLC2016


Doyon Utilities FRA, FWA, FGA Medium Conductor (#1/0 Raven)

Conductor RAVEN #1/0 AWG 6/ 1 Stranding ACSR Area= .0968 Sq. in Dia= .398 in Wt= .145 lb/ft RTS= 4380 lb Data from Chart No. 1-938 English Units Using Exact Catenary Equations

Span= 150.0 feet NESC Heavy Load Zone Creep is NOT a Factor Rolled Rod Design Points Final Initial Temp Ice Wind K Weight Sag Tension Sag Tension F in psf lb/ft lb/ft ft lb ft lb 0. .75 .00 .00 1.216 2.51 1364. 2.51 1364. 0. .50 4.00 .30 1.144 2.44 1320. 2.43 1327. 32. .50 .00 .00 .703 2.30 862. 2.10 942. 40. .00 25.00 .00 .842 2.55 929. 2.38 997. -20. .00 .00 .00 .145 .50 809. .43 953. -10. .00 .00 .00 .145 .58 704. .47 876.* 0. .00 .00 .00 .145 .68 604. .51 798. 30. .00 .00 .00 .145 1.13 363. .72 566. 60. .00 .00 .00 .145 1.72 237. 1.11 368. 90. .00 .00 .00 .145 2.08 196. 1.65 247. 120. .00 .00 .00 .145 2.34 174. 2.19 186. 167. .00 .00 .00 .145 2.73 149. 2.67 153. 212. .00 .00 .00 .145 3.09 132. 3.03 135. * Design Condition

Span= 200.0 feet NESC Heavy Load Zone Creep is NOT a Factor Rolled Rod Design Points Final Initial Temp Ice Wind K Weight Sag Tension Sag Tension F in psf lb/ft lb/ft ft lb ft lb 0. .75 .00 .00 1.216 3.92 1553. 3.92 1553. 0. .50 4.00 .30 1.144 3.82 1498. 3.80 1508. 32. .50 .00 .00 .703 3.56 988. 3.26 1079. 40. .00 25.00 .00 .842 3.90 1080. 3.65 1156. -20. .00 .00 .00 .145 .99 731. .76 951. -10. .00 .00 .00 .145 1.14 638. .83 876.* 0. .00 .00 .00 .145 1.31 554. .90 801. 30. .00 .00 .00 .145 1.98 367. 1.24 585. 60. .00 .00 .00 .145 2.70 269. 1.77 409. 90. .00 .00 .00 .145 3.11 233. 2.44 297. 120. .00 .00 .00 .145 3.43 212. 3.10 234. 167. .00 .00 .00 .145 3.91 186. 3.81 191. 212. .00 .00 .00 .145 4.34 167. 4.25 171. * Design Condition�


Span= 250.0 feet NESC Heavy Load Zone Creep is NOT a Factor Rolled Rod Design Points Final Initial Temp Ice Wind K Weight Sag Tension Sag Tension F in psf lb/ft lb/ft ft lb ft lb 0. .75 .00 .00 1.216 5.51 1726. 5.51 1726. 0. .50 4.00 .30 1.144 5.39 1662. 5.35 1673. 32. .50 .00 .00 .703 5.00 1101. 4.57 1203. 40. .00 25.00 .00 .842 5.42 1216. 5.07 1300. -20. .00 .00 .00 .145 1.70 668. 1.20 948. -10. .00 .00 .00 .145 1.92 590. 1.29 876.* 0. .00 .00 .00 .145 2.17 523. 1.41 805. 30. .00 .00 .00 .145 3.00 378. 1.88 604. 60. .00 .00 .00 .145 3.83 296. 2.54 446. 90. .00 .00 .00 .145 4.26 266. 3.32 342. 120. .00 .00 .00 .145 4.63 245. 4.08 278. 167. .00 .00 .00 .145 5.18 219. 5.05 225. 212. .00 .00 .00 .145 5.70 199. 5.56 204. * Design Condition Certain information such as the data, opinions or recommendations set forth herein or given by AFL representatives, is intended as a general guide only. Each installation of overhead electrical conductor, underground electrical conductor, and/or conductor accessories involves special conditions creating problems that require individual solutions and, therefore, the recipient of this information has the sole responsibility in connection with the use of the information. AFL does not assume any liability in connection with such information.�



Doyon Utilities FRA, FWA, FGA Medium Conductor (4/0 ACSR Sparate)

Conductor PENGUIN #4/0 AWG 6/ 1 Stranding ACSR Area= .1939 Sq. in Dia= .563 in Wt= .291 lb/ft RTS= 8350 lb Data from Chart No. 1-938 English Units Using Exact Catenary Equations

Span= 200.0 feet NESC Heavy Load Zone Creep is NOT a Factor Rolled Rod Design Points Final Initial Temp Ice Wind K Weight Sag Tension RTS Sag Tension RTS F in psf lb/ft lb/ft ft lb % ft lb % 0. .75 4.00 .00 1.664 3.50 2383. 28.5 3.50 2383. 28.5 0. .50 4.00 .30 1.385 3.25 2136. 25.6 3.19 2171. 26.0* 32. .50 .00 .00 .952 3.30 1445. 17.3 3.06 1558. 18.7 -40. .00 .00 .00 .291 .89 1634. 19.6 .82 1783. 21.4 -20. .00 .00 .00 .291 1.16 1252. 15.0 .98 1488. 17.8 0. .00 .00 .00 .291 1.55 941. 11.3 1.21 1204. 14.4 30. .00 .00 .00 .291 2.26 644. 7.7 1.72 846. 10.1 60. .00 .00 .00 .291 2.97 491. 5.9 2.38 613. 7.3 90. .00 .00 .00 .291 3.52 414. 5.0 3.03 480. 5.8 120. .00 .00 .00 .291 3.82 381. 4.6 3.64 401. 4.8 167. .00 .00 .00 .291 4.28 340. 4.1 4.24 344. 4.1 212. .00 .00 .00 .291 4.70 310. 3.7 4.65 313. 3.8 * Design Condition

Span= 225.0 feet NESC Heavy Load Zone Creep is NOT a Factor Rolled Rod Design Points Final Initial Temp Ice Wind K Weight Sag Tension RTS Sag Tension RTS F in psf lb/ft lb/ft ft lb % ft lb % 0. .75 4.00 .00 1.664 4.38 2407. 28.8 4.38 2407. 28.8 0. .50 4.00 .30 1.385 4.11 2137. 25.6 4.04 2171. 26.0* 32. .50 .00 .00 .952 4.16 1449. 17.4 3.90 1548. 18.5 -40. .00 .00 .00 .291 1.38 1331. 15.9 1.20 1537. 18.4 -20. .00 .00 .00 .291 1.80 1022. 12.2 1.46 1263. 15.1 0. .00 .00 .00 .291 2.31 799. 9.6 1.81 1019. 12.2 30. .00 .00 .00 .291 3.09 596. 7.1 2.47 744. 8.9 60. .00 .00 .00 .291 3.82 483. 5.8 3.20 577. 6.9 90. .00 .00 .00 .291 4.39 420. 5.0 3.88 476. 5.7 120. .00 .00 .00 .291 4.71 391. 4.7 4.50 410. 4.9 167. .00 .00 .00 .291 5.20 355. 4.2 5.15 358. 4.3 212. .00 .00 .00 .291 5.64 327. 3.9 5.59 330. 4.0 * Design Condition�


Span= 250.0 feet NESC Heavy Load Zone Creep is NOT a Factor Rolled Rod Design Points Final Initial Temp Ice Wind K Weight Sag Tension RTS Sag Tension RTS F in psf lb/ft lb/ft ft lb % ft lb % 0. .75 4.00 .00 1.664 5.36 2428. 29.1 5.36 2428. 29.1 0. .50 4.00 .30 1.385 5.07 2139. 25.6 4.99 2171. 26.0* 32. .50 .00 .00 .952 5.13 1453. 17.4 4.83 1541. 18.4 -40. .00 .00 .00 .291 2.12 1075. 12.9 1.76 1293. 15.5 -20. .00 .00 .00 .291 2.66 855. 10.2 2.15 1060. 12.7 0. .00 .00 .00 .291 3.23 705. 8.4 2.61 871. 10.4 30. .00 .00 .00 .291 4.04 564. 6.7 3.38 674. 8.1 60. .00 .00 .00 .291 4.77 477. 5.7 4.13 551. 6.6 90. .00 .00 .00 .291 5.36 425. 5.1 4.82 472. 5.7 120. .00 .00 .00 .291 5.70 400. 4.8 5.46 417. 5.0 167. .00 .00 .00 .291 6.21 367. 4.4 6.15 370. 4.4 212. .00 .00 .00 .291 6.67 342. 4.1 6.62 344. 4.1 * Design Condition Certain information such as the data, opinions or recommendations set forth herein or given by AFL representatives, is intended as a general guide only. Each installation of overhead electrical conductor, underground electrical conductor, and/or conductor accessories involves special conditions creating problems that require individual solutions and, therefore, the recipient of this information has the sole responsibility in connection with the use of the information. AFL does not assume any liability in connection with such information.�



Fort Wainwright Merlin, 336.4ACSR By CTD

Conductor MERLIN 336.4 Kcmil 18/ 1 Stranding ACSR Area= .2789 Sq. in Dia= .684 in Wt= .365 lb/ft RTS= 8680 lb Data from Chart No. 1-844 English Units Using Exact Catenary Equations

Span= 150.0 feet NESC Heavy Load Zone Creep is NOT a Factor Rolled Rod Design Points Final Initial Temp Ice Wind K Weight Sag Tension RTS Sag Tension RTS F in psf lb/ft lb/ft ft lb % ft lb % 0. .75 .00 .00 1.702 1.56 3078. 35.5 1.56 3078. 35.5 0. .50 4.00 .30 1.536 1.45 2975. 34.3 1.44 3000. 34.6* 0. .25 9.22 .00 1.121 1.16 2724. 31.4 1.12 2814. 32.4 32. .50 .00 .00 1.101 1.54 2013. 23.2 1.39 2223. 25.6 60. .00 23.08 .00 1.365 2.13 1805. 20.8 1.94 1980. 22.8 -40. .00 .00 .00 .365 .30 3406. 39.2 .30 3406. 39.2 -20. .00 .00 .00 .365 .34 2978. 34.3 .34 2996. 34.5 0. .00 .00 .00 .365 .44 2348. 27.0 .40 2556. 29.5 30. .00 .00 .00 .365 .70 1465. 16.9 .55 1850. 21.3 40. .00 .00 .00 .365 .85 1212. 14.0 .64 1610. 18.5 50. .00 .00 .00 .365 1.03 997. 11.5 .75 1375. 15.8 60. .00 .00 .00 .365 1.24 827. 9.5 .89 1156. 13.3 70. .00 .00 .00 .365 1.47 700. 8.1 1.07 963. 11.1 80. .00 .00 .00 .365 1.69 607. 7.0 1.27 807. 9.3 90. .00 .00 .00 .365 1.91 537. 6.2 1.49 688. 7.9 120. .00 .00 .00 .365 2.50 411. 4.7 2.14 480. 5.5 167. .00 .00 .00 .365 3.04 338. 3.9 2.98 345. 4.0 212. .00 .00 .00 .365 3.33 309. 3.6 3.31 311. 3.6 * Design Condition Certain information such as the data, opinions or recommendations set forth herein or given by AFL representatives, is intended as a general guide only. Each installation of overhead electrical conductor, underground electrical conductor, and/or conductor accessories involves special conditions creating problems that require individual solutions and, therefore, the recipient of this information has the sole responsibility in connection with the use of the information. AFL does not assume any liability in connection with such information.�



Fort Wainwright Merlin, 336.4ACSR By CTD

Conductor MERLIN 336.4 Kcmil 18/ 1 Stranding ACSR Area= .2789 Sq. in Dia= .684 in Wt= .365 lb/ft RTS= 8680 lb Data from Chart No. 1-844 English Units Using Exact Catenary Equations

Span= 200.0 feet NESC Heavy Load Zone Creep is NOT a Factor Rolled Rod Design Points Final Initial Temp Ice Wind K Weight Sag Tension RTS Sag Tension RTS F in psf lb/ft lb/ft ft lb % ft lb % 0. .75 .00 .00 1.702 2.73 3115. 35.9 2.73 3115. 35.9 0. .50 4.00 .30 1.536 2.59 2970. 34.2 2.56 3000. 34.6* 0. .25 9.22 .00 1.121 2.16 2597. 29.9 2.07 2707. 31.2 32. .50 .00 .00 1.101 2.70 2038. 23.5 2.49 2208. 25.4 60. .00 23.08 .00 1.365 3.46 1976. 22.8 3.23 2113. 24.3 -40. .00 .00 .00 .365 .59 3084. 35.5 .59 3084. 35.5 -20. .00 .00 .00 .365 .73 2491. 28.7 .69 2661. 30.7 0. .00 .00 .00 .365 .96 1907. 22.0 .82 2215. 25.5 30. .00 .00 .00 .365 1.53 1190. 13.7 1.18 1543. 17.8 40. .00 .00 .00 .365 1.79 1020. 11.8 1.36 1338. 15.4 50. .00 .00 .00 .365 2.06 886. 10.2 1.58 1155. 13.3 60. .00 .00 .00 .365 2.34 781. 9.0 1.83 1000. 11.5 70. .00 .00 .00 .365 2.61 700. 8.1 2.09 874. 10.1 80. .00 .00 .00 .365 2.87 637. 7.3 2.36 775. 8.9 90. .00 .00 .00 .365 3.12 586. 6.7 2.62 696. 8.0 120. .00 .00 .00 .365 3.81 480. 5.5 3.37 542. 6.2 167. .00 .00 .00 .365 4.63 395. 4.6 4.37 419. 4.8 212. .00 .00 .00 .365 4.98 368. 4.2 4.96 369. 4.2 * Design Condition Certain information such as the data, opinions or recommendations set forth herein or given by AFL representatives, is intended as a general guide only. Each installation of overhead electrical conductor, underground electrical conductor, and/or conductor accessories involves special conditions creating problems that require individual solutions and, therefore, the recipient of this information has the sole responsibility in connection with the use of the information. AFL does not assume any liability in connection with such information.�




INDEX OF DRAWINGS / CONSTRUCTION UNITS

Drawing No. Title

OVERHEAD UNITS

Single-Phase Pole Top (A Assemblies)

A1.0 ........................ Single Support Assemblies Miscellaneous VA1.0 ...................... Single Support Assemblies Miscellaneous (V)A1.2 ................... Single Support, Tangent (V)A1.11 ................. Single Support, Tangent, Crossarm (V)A2.21 ................. Double Support on Crossarms (V)A5.1 ................... Single Deadend, Vertical (V)A5.31 ................. Single Deadend on Crossarms (V)A5.31X ............... Single Deadend on Crossarms (V)A6.1 ................... Double Deadend (Straight), Vertical (V)A6.21 ................. Double Deadend, Neutral on Crossarm (V)A6.31 ................. Double Deadend, Neutral on Crossarms

Three-Phase Pole Top (C Assemblies)

(V)C1.11/.12 ........... Single Support on Crossarm (V)C.11L/.12L .......... Single Support on Crossarm (Large Conductor) (V)C1.11RX/.12RX... Single Support on Crossarm (Raptor Protection) (V)C1.41 .................. Single Support, Neutral on Crossarm (V)C1.41L ................ Single Support, Neutral on Crossarm (Large Conductor) (V)C2.21 .................. Double Support on Crossarms (V)C2.21L ................ Double Support on Crossarms (Large Conductor) (V)C2.51 .................. Double Support, Neutral on Crossarm (V)C2.51L ................ Double Support, Neutral on Crossarm (Large Conductor) (V)C2.52L ................ Double Support, Neutral on Crossarm (Large Conductor) (V)C2.52LX .............. Double Support on 10 Foot Crossarms (Large Conductor) Upper Circuit (V)C3.1X.................. Suspension Angle (Large Conductor) (V)C3.2X.................. Suspension Angle (V)C5.21/.31 ........... Single Deadend on Crossarms (V)C5.31X ............... Single Deadend, Neutral on Crossarm (V)C5.71L ................ Single Deadend on Crossarm Assembly (V)C5.71LX .............. Single Deadend, Neutral on Crossarm (Large Conductor) (V)C5.71LAX............ Single Deadend on Crossarm Assembly (Large Conductor), No Neutral (V)C6.52LX .............. Double Deadend, Neutral on Crossarm (Large Conductor) (V)C6.53X ............... Double Deadend, Neutral on Crossarm (V)C6.91G ............... Double Deadend (Buckarms) Guide (V)C6.91GX ............. Double Deadend (Buckarms) Guide (Large Conductor)



Double Circuit Guides (D Assemblies)

(V)D.1GX ................. Single Support, Neutral on Crossarm, Double Circuit Guide (V)D.2GX ................. Single Support, Neutrals on Crossarms, Double Circuit Guide

Guy Assemblies (E Assemblies)

E1.1X ...................... Single Down Guy – Light Duty (Rams Head Type) E2.1X ...................... Single Down Guy – Heavy Duty (Through Bolt Type) E2.2X/.2AX ............. Double Down Guy – Heavy Duty (Through Bolt Type) E2.3X/.3AX ............. Triple Down Guy – Heavy Duty (Through Bolt Type) E2.GX ...................... Guying Design Guide E2.02X/.03X ............ Single Overhead Guy – Heavy Duty (Through Bolt Type) E5.1X ...................... Guy Strain Insulator

Anchor Assemblies (F Assemblies)

F2.XX ...................... Screw Anchors (Power Installed) F3.XX ...................... Plate Type Anchors

Transformer Assemblies (G Assemblies)

(V)G1.4 ................... Single-Phase, Conventional Transformer (Tangent Pole) (V)G1.6 ................... Single-Phase, Conventional Transformer (Deadend Pole) (V)G3.3 ................... Three-Phase Transformer Bank, Grounded-Wye Primary, Grounded-Wye 4 Wire ............................... Secondary

Grounding Assemblies (H Assemblies)

H1.1 ........................ Grounding Assembly, Ground Rod Type H1.1PX .................... Grounding Assembly, H-Pile Installation H4.1 ........................ Grounding Assembly, Platform Type (For Sectionalizing Air Break Switch)

Secondary Assemblies (J Assemblies)

J1.1/.2 ..................... Secondary Assemblies (Small Angle) J2.1/.2 ..................... Secondary Assemblies (Large Angle) J3.1/4.1................... Secondary Assemblies (Deadend, Misc.)

Miscellaneous Assemblies (M Assemblies)

M1.30G .................. Right-of-Way Clearing Guide M3.1X ..................... Pole Numbering M3.2GX .................. Overhead Equipment Identification and Labeling Guide M31-P ..................... Pole Foundation, H-Pile Installation M-BOL .................... Bollard, Protective Post Assembly Detail M-MKR-LT .............. Overhead Distribution Marker Light M-SS-MNT-A .......... Self-Supporting Service Mounting Assembly for 100A or 200A Services M-SS-MNT-B ........... Self-Supporting Service Mounting Assembly for 400A, 600A or 800A Services



Protection Assemblies (P Assemblies)

(V)P1.3 .................... Surge Arresters – 3 Single Phase

Metering Assemblies (Q Assemblies)

(V)Q4.1X ................. Primary Metering Three-Phase (4 Wire Grounded Wye)

Sectionalizing Assemblies (S Assemblies)

(V)S1.01/.02 ........... Miscellaneous Cutouts and Disconnect Switch (V)S1.1 .................... Cutout, Single-Phase (V)S1.3 .................... Cutouts, Three Single-Phase (V)S2.32X ................ Group-Operated Air Break Switch, 3-Phase Primary

UNDERGROUND UNITS

RISER ASSEMBLIES

(V)UA3 .................... Single-Phase Cable Terminal Pole with Arrester and Crossarm Mounted Cutout (V)UC1X .................. Three-Phase Cable Terminal Pole with Cutouts and Crossarm Mounting ............................... Arresters (V)UC5X .................. Three-Phase Cable Terminal Pole with 600A Load Break and Crossarm Mounting ............................... Arresters UM5X ..................... Secondary Cable Terminal Pole

TRANSFORMER ASSEMBLIES

(V)UG7-2/3 ............. Single-Phase Pad-Mounted Transformer (V)UG17-2/3 ........... Three-Phase Pad-Mounted Transformer

SECONDARY PEDESTALS

UK5/UK5-1 ............. Secondary Pedestal Assembly, (UK5 Single-Phase, UK5-1 Three-Phase)

PAD ASSEMBLIES

UM1-1 .................... Single-Phase Transformer (25 kVA – 75 kVA) UM1-1A .................. Single-Phase Transformer (Large), Three-Phase Transformer (Cooper 12.47 kV, ............................... 75 and 150 kVA) UM1-1B .................. Three-Phase Transformer (75 kVA – 750 kVA)/Three-Phase Junction Box UM1-1C .................. Single-Phase Junction Box UM1-1F .................. 600A Switch Cabinet, 15 kV PMH UM1-1G .................. 600A Switch Cabinet, 15 kV PME UM1-1H .................. 600A Switch Cabinet, 25 kV PME UM1-1X-C ............... Pad Opening Cover – Transformer/Jbox/Switch

SECTIONALIZING ASSEMBLIES

(V)UM3E-3X............ Three-Phase Switch Cabinet Enclosure, 600A Pad Mounted



(V)UM31X-# ........... Single-Phase Sectionalizing Enclosure, Pad Mounted (V)UM33X-# ........... Three-Phase Sectionalizing Enclosure, Pad Mounted

MISCELLANEOUS ASSEMBLIES

(V)UM6-XX ............. Miscellaneous Accessories Underground

TRENCH/CONDUIT ASSEMBLIES

UR2 ......................... Trench for Direct Bury Cable and Conduit (UR2, UR2-H, UR2-1, UR2-2) URC-XX ................... Conduit Crossing Assembly, Road (Open Cut or Bore), Parking Lot or Driveway ............................... (Gravel or Paved) UR-DB ..................... Duct Bank (Concrete Encased Trench) UM50-X-X ............... Miscellaneous Conduit Installation Conduit Elbows ...... Conduit Elbow Guide

UNDERGROUND LABELING GUIDES

UM2.1GX ................ Underground Equipment Identification and Labeling Guide UM2.2GX ................ Cable Tagging Assemblies

LIGHTING UNITS

LOAD CENTER ASSEMBLIES

LC-01-1-B ................ Single-Phase Lighting Loadcenter LC-01-2-B ................ Three-Phase Lighting Loadcenter

PILE FOUNDATION ASSEMBLIES

LC-DEMB ................ Direct Imbed Foundation LF-CSL ..................... Concrete Street Light Foundation LF-CPL ..................... Concrete Parking Lot Foundation LF-CPL-P .................. Concrete Parking Lot Pile Foundation

MISCELLANEOUS ASSEMBLIES

LJB .......................... Junction Box

End of Index of Drawings / Construction Units

2016 d onstruction tandards electrical distribution system · 2016-08-22 · 2016 design and...

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