Attachment_1_-_SOW.pdf

AWUB 07-0110

Work Request No. 36079

Statement of Work Repair Electrical Equipment with Pad Mounted on Davis Rd

11/20/14

All work described herein shall be performed in fullest compliance with Construction Standard policy of Barksdale AFB Design Compatibility Guidelines, comply with base standards, latest OSHA, IES, NEC, NEMA, IEEE, UFC 3-550-01 and all local rules and regulations for the design and other guidance stated in the following scope of work.

Construction shall be conducted in a quality workmanlike manner. Completed work shall exhibit superior quality for completed work.

The contractor shall coordinate with Electric Shop, de-energize the source of electrical supply and follow all safety lock out and tag out procedure for all electrical work. The Contractor shall obtain digging permit for all underground work including but not limited to demotion of wood poles, installation of new duct bank and excavation, back filling or soil boring for new conduits and installation of man holes, new ground rods, new concrete pads, and new bollards. The Contractor shall ensure that all excavated/work areas are barricaded.

The Contractor shall ensure that all work is in compliance with applicable OSHA 1926 Construction Standards. The contactor shall coordinate with Base personnel before any kind of underground work. Contractor shall take all precaution not to disturb any underground utilities including gas, electric, Comm, telephone, cable, water and sewer.

To protect workers, contractor work areas shall be isolated and access by Air Force personnel restricted, unless working in conjunction with the contractor. If this is impractical or cannot be accomplished, the on-site supervisor shall assure the contractor‘s compliance with proper work procedures, energy isolation procedures and contractor employee compliance. 91-203, para 21.8.3. When contractor personnel are engaged in activities covered by this instruction (Air Force facilities), the on-site supervisor and contractor shall inform each other of their respective lockout/tag out procedures. The on-site supervisor shall ensure his/her personnel understand and comply with the contractor‘s energy control procedures. Air Force and contractor personnel conducting joint lockout/tagout operations shall use requirements in this standard 91-203, para 21.8.1. The Contractor shall follow confine space procedures per OSHA standards and AF guidance while performing work in the confined space areas.

Existing medium voltage (12.47 kV) primary feeder 10 feeds existing pad mounted vista switch PMS10-4840. This PMS is supplying power to Building B4186 via pad mounted transformer T4186 and Building B4173 via two (2) transformers TP4173A and TP4173B on poles 10-87 and 10-88 respectively. Also, third source of power supply is coming to Building B4173 via existing 125 Amp, 120/208 Volt, 3 Ø, 4 wire breaker in the existing outdoor panel near existing outdoor pad mounted transformer near Building B3873. So, there are multiple service entrances for Building B4173. Also, all panels inside B4173 are

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Attachment 1

SOW‐ AWUB 07‐0110 11/20/14

very old and are in bad shape. Some of the disconnect switches are mounted very high and they cannot be reachable without ladder. Also, there is not enough working clearance in the training room closet. Also, these pole mounted transformers TP4173A and TP4173B, switches, and other pole mounted equipment along Davis Road are degraded due to age and deterioration. The breakdown of these equipment will cause extensive power outage and delay vital Base functions. So, the purpose of this contract is to remove multiple service entrances by removing two (2) pole mounted transformers, overhead 12.47 kV primary distribution lines, and remove all associated poles 10-84, 10-85, 10-86, 10-87, and 10-87, and remove 125 A, 120/208, 3Ø feeder feeding this building B4173 and provide new 12.47 kV supply to this Building B4173. Also, the contractor shall provide all new power panels and all new main feeders from new 1600 AF/1200AT, 120/208 V, 3Ø, 4W switchboard to all new or existing panels. Also, contractor shall remove the existing panels in the training room and install new panels in the new electrical room in the corridor. If the panel is near the life expectancy, the contractor shall change it. The contractor shall provide line item estimate for providing and installing additional five (5) new panels. The contractor shall demolish all existing unused boxes, switches, boxes, switches, gutter, conduits, wiring from training room and other area and remove associated conduits and wiring all way to the source of supply

The contractor shall coordinate with Civil/Architectural Contractor and provide all labor, equipment, supplies, and material for the Architectural, Civil and Electrical work mentioned below.

Architectural:

Please see attached architectural design drawings

Civil Work

Coordinate with Base Civil Engineer regarding any Civil Work

Electrical

1. The Contractor shall coordinate with electric shop and deenergize 12.47 kV feeder 10 feeding Buildings B4186, and B4173. The contractor shall follow all safety lock out and tag out procedures. After deenergizing the primary power line, the contractor shall disconnect the existing cables from existing PMS 10-4840 and from all poles (10-84, 10-85, 10-86, 10-87, 10-88) and transformers TP4173A &

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TP4173B and transformer . The Contractor shall remove the existing cables and all above mentioned poles. The contractor shall reconnect those existing cables to new pad mounted outdoor Vista PMS 10-4840.

2. After removing the pole mounted transformers, the Contractor shall remove all existing old cables and conduits going to the existing panels in Building B 4173.

3. The Contractor shall deenergize existing 400A, 120/208 volt, 3 ph, 4w outdoor panel near Bldg B3873 and remove existing 150A, 120/208 Volt, 3 ph, 4 W breaker. The Contractor shall remove cables and conduits going from that breaker to the existing panel in B4173.

4. Two (2) new S & C Pad Mounted Dead Front Loop Feed S & C Pad Mounted Switches (PMSs) - See attached specs.

5. Provide new indoor 1600 Amp., 120/208 volt, 3Ø, 4 wire switchboard in NEMA 12 enclosure. - See attached specs.

6. The contractor shall coordinate the construction work to minimize the duration of power outages to Buildings B4173, and other affected buildings like B4186 by first installing the new primary underground duct bank, new underground secondary feeders, two (2) new PMS, one new 500 KVA, 12.47 kV/208/120V, 3Ø pad mounted outdoor transformer B4173, new 1600 Amp 208/120 V, 3Ø, 4 W MDP and then demolishing the existing overhead lines and other existing source.

7. The Contractor shall install 2- 3/c#350 KCM 15 KV, MV-105, concentric neutral copper cable in 2-6” conduits in concrete encased underground duct bank from new PMS-10-4840 to new PMS-10-4173 as shown on the drawing. The new cable shall be 15 kV rated, copper conductor, copper 1/3 concentric neutral wire, high dielectric strength EPR insulated, 133% insulation level, encapsulating linear low density polyethylene (LLDPE) jacket, suitable for underground application in conduit/duct bank in wet and dry locations. Perform High potential (Hi Pot) test on new 15 kV cables and submit the certified test results. Also, submit the calibration report of the Hi-pot test equipment.

8. Provide and install one (1) new loop feed, deadfront, pad mounted 500 KVA, 3 phase, 12.47 kV primary delta – 120/208 V Y grounded secondary transformer T- 4173. The new transformer shall be outdoor type, pad mounted, whether proof, rain, snow, water tight 12,470 volt 3-phase delta primary – 120/208 volt secondary, 3

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phase, non-PCB oil filled KNAN type. The transformers shall meet most recent revisions of: IEEE C57.12.00, ANSI C57.12.25, ANSI C57.12.28, IEEE C57.12.70, IEEE C57.12.80, IEEE C57.12.90, IEEE C57.147, IEEE 386, ANSI Z535, NEMA

260, and NEMA TR-1. Provide and install concrete pads and bollards for all new outdoor transformers and switches. The transformer shall be anchored to the new concrete pad. The new transformer shall be equipped with Cooper primary fuses and Cooper isolation links. The new transformer shall have oil level gauge, oil temperature gauge, pressure/vacuum gauge, pressure relief device- self sealing, drain valve with sampler in LV compartment, 300 A, 4 position load break switch, stainless steel grounding pads in HV and in LV compartments, mounting provisions for current transformers and potential transformers and full capacity primary voltage tap changer. The new transformer shall have class H or better insulation. It shall have primary BIL 95 kV and secondary BIL 30 kV. The transformer shall have full-capacity voltage taps total: four: 2.5 percent taps, 2 above and 2 below rated high voltage; with externally operable tap changer for de-energized use and with position indicator and padlock hasp. The 4 position load break switch shall be high voltage switch, 300A, make-and-latch rating of 10-kA RMS, symmetrical, arranged for loop feed with 3-phase, 4-position, gang-operated, load-break switch that is oil immersed in transformer tank with hook-stick operating handle in primary compartment. It shall have 9 kV arrestor, current transformers and fuse block with fuses. The manufacturer of the transformer shall provide anchoring and anchoring hardware including anchor bolts to mount the transformer to the new concrete pad. The transformer shall be anchored to the concrete pad. The new transformer shall meet the arc flash requirement per OSHA standard and shall have arc flash labels. The new transformers shall be UL listed and shall have UL labels. The new transformer shall have manufacturer furnished name plate that includes minimum but not limited to KVA rating, %Z, primary/secondary voltage, weight of transformer with oil and without oil and weight of transformer oil, type of oil, volume and flash point of oil, winding and tap settings information, etc… Label per Barksdale standards with KVA, voltage etc... as below:

Transformer Label T 7710 A?

KVA

Live or Dead Front Primary Voltage (examples: 12470 Delta, 12470GRDY) Secondary Voltage (examples: 120/208, 120/240, 277/480)

Note: If transformer feeds more than one building they need to be listed also.

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Switch Label

Switch number located in the top right corner of switch on street side with following information:

PMS Feeder #-Building #. (Example: PMS 9-5576)

Also each switch needs to be labeled to what it feeds located below switch on Vista switches and on the top middle of each door on live front switches.

Example:

To PMS 9-5546 To PMS 9-5645 To T-6413B To PMS 9-6415

Also, provide and install arc flash labels for all electrical equipment including new furnished under this contract per OSHA and UFC.

9. PAD: 3000 PSI 6” thick with a 12” footer, A ¾” chamfer on all edges, One foot clearance on all sides of the equipment to be placed on the pad, no more than 3” above finished grade, with windows blocked out and after curing the blocks removed and the windows filled with gravel to 1” of the top and capped with mortar, calk around all entrances and around mortar to prevent ants from coming in, all cable entrances shall be protected by schedule 40 PVC or coated RGS, 4” x 5’ RGS bollards filled with concrete placed 2’ in the ground (not in the concrete pad) one in each of the four corners at equal height, painted Barksdale brown federal spec 20117.

A. The new transformers shall be built in compliance with all ANSI/IEEE and NEMA standards. The new transformers shall also meet Air Force Base Standards. The new transformers shall be painted Barksdale Brown in color per Spec. 20117. The new transformers shall have copper primary and secondary windings. The minimum guaranteed efficiency shall be 99.02%. The new transformers shall meet the arc flash requirement per OSHA standard and shall have arc flash labels. The new transformers shall be UL listed and shall have UL labels. The transformers shall have fire resistant construction and minimum separation of 15’ from the building per UFC 3-600-01, Table 6-1. Provide grounding for the new transformers per latest NEC, UFC, IEEE and Barksdale Standards. Ground pad

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mounted equipment and non-current carrying metal items. The contractor shall store transformer protected from weather, so condensation will not form on or in unit. Provide temporary heating according to manufacturer's written instructions.

The contractor shall provide and install a new KWH smart meter per Barksdale standards and one multimeter on line side of MDP with all necessary CT’s. The multimeters shall read currents (line currents in all three lines, and current in the neutral) voltages (VAB, VBC, VCA, VAN,VBN, VCN), power factor, harmonic distortion, VAR etc. the contractor shall provide the necessary CTs for KWH meter and multimeter. The contractor shall calibrate the KWH meter and multimeters with new CTs ratio and meters shall read the data correctly. The contractor / manufacturer shall fabricate, provide and install new primary fuses in the new transformer cabinet. The transformer manufacturer shall provide the time current curve of the fuses that shall be coordinated with the new electronic fuse settings in the new S & C Pad Mounted Switches (PMS).

Counterpoise: Install bare copper conductor not less than 1/0 for ground ring, and 1/0 AWG for taps to equipment grounding terminals. Ground rods shall be of copper clad steel, or solid copper 3/4 inch diameter x 10 ft long. Bury ground ring 30” deep and not less than 30” from the pad. Provide new bollards for each transformer/switch and the bollards shall not be in the pads. Bond each bollard to the ground ring. Install four ground rods, one at each corner of ground ring around the pad. Provide 2 paths into the transformer compartments one from each side. cad weld conductor at each ground rod.

The Contractor/ manufacturer shall submit the shop drawing submittal of the transformers containing product data that includes rated nameplate data, capacities, weights, dimensions, minimum clearances, installed devices and features, location of each field connection, and performance for each type and size of transformer indicated, power wiring diagrams, floor plans drawn to scale with the following items

1. Underground primary and secondary conduit stub-up location.

2. Dimensioned concrete base, outline of transformer, and required clearances.

Ground rods and grounding cable locations

The manufacturer shall perform the standard factory tests on the new transformer in accordance with ANSI/IEEE standard C57.12.90. The test shall include minimum, resistance measurements of all windings on rated-voltage connection and on tap extreme connections, Ratios on rated-voltage connection and on tap extreme connections, Polarity and phase relation on rated-voltage connection, oil leak test, FA4608-15-R-0006

No-load loss at rated voltage on rated-voltage connection, Excitation current at rated voltage on rated-voltage connection, Impedance and load loss at rated current on rated-voltage connection and on tap extreme connections, Applied potential, Induced potential, Temperature test.

If any of the above tests fail, the manufacturer shall take corrective actions and fix the problem, and certify the satisfactory operation of the transformer before shipping the transformer.

The manufacturer shall submit the signed certified factory tests results and satisfactory operation of the transformer.

After installing transformers but before primary is energized, contractor shall test and verify that grounding system and should be at latest NEC specified value or less.

10. Follow all safety lockout and tag out procedures.

11. Provide new concrete encased duct bank with 4 -6”C and run new 2- 15 kV, 3/c #350 KCM, MV-105, concentric neutral (1/3 copper neutral in each cable), 133% insulation from new PMS 10-4840 to new PMS 10-4173 in (2) – 6” schedule 40 PVC conduit in the new concrete encase duct bank as shown on the drawing.

Provide and install new concrete encased duct bank from new Man Hole 2 to new PMS-4173 as shown in Section 2-2 on the dwg. Also, provide and install new concrete encased duct bank from new Man Hole 2 to new pad mounted transformer T4173. Two (2) 6”conduits shall be spare in the duct bank. Schedule 40 PVC shall be supported every 5’ with conduit supports. All bends greater than 45 degrees shall be RGS. Concrete encased primary duct bank shall be with sprinkled red dye.

Encapsulate ducts with a minimum of 3” of concrete. Top of concrete will be a minimum of 36’ below grade. Back fill with clean dirt to 1’ below grade and install a 6” DANGER ELECTRICAL marking tape then fill trench and compact dirt. The new cable shall be 15 kV rated, copper conductor, copper 1/3 concentric neutral wire, high dielectric strength EPR insulated, 133% insulation level, encapsulating linear low density polyethylene (LLDPE) jacket, suitable for underground application in conduit/duct bank in wet and dry locations. Perform high potential on high voltage cables and megger test on low voltage secondary cables from secondary of the transformer to the new MDP and from new MDP to all existing panels in accordance with IEEE standards. Meg or insulation resistance testing for low voltage cable under 600 volts is also required per NEC.

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12. Provide and install all new cables in the new 6” PVC duct banks from the new PMS to all new transformers as shown on the drawings. The location of the new duct bank, new manholes, new PMS are approximate. The Contractor shall coordinate with electric shop for the exact locations of manholes and PMS.

13. Provide and install three (3) new 8’ x 10’ x10’ manholes with 36” diameter steel cover lid with the word “ELECTRIC” formed into this lid. Shall be constructed of reinforced concrete which may be monolithically constructed pre cast concrete.

New manholes shall have H-20 structural load rating according to AASHTO HB 17.

Duct lines shall enter manholes through preordered factory installed knock outs as necessary to meet the project requirements. Required conduit be installed flush with bell ends and sealed around openings. Manhole covers shall be installed no more than 3” above finished grade. A cast metal grille type sump frame and cover shall be installed over the manhole sump hole. Drill hole in the manhole corner and drive a 3/4” x 10’ copper clad ground rod into the earth so that approximately 4” of the ground rod will extend above the manhole floor then seal around ground rod in the manhole floor. A #4 bare stranded ground wire shall be cad welded to the ground rod and encircle the manhole 4’ above the floor anchored to the wall and bonded to cable racks and other metal. A cable pulling iron shall be installed in the wall opposite each duct line entrance and in center of the floor such that it doesn’t present a tripping hazard. Cables shall be securely supported from walls by the hop dip galvanized cable racks with stand offs fitted with porcelain insulators. Install eight cable racks with two spare standoffs on each cable rack two cable racks per wall per manhole (five total standoffs per rack and rack each separate. Fireproof cable and label with tags. Tags shall have conductor size, conductor material, Feeder # and what it connects to.

14. Install manholes every 500’ of straight run and within 100’ of the electrical equipment as shown on the drawing.

15. Install pull boxes every 200’ on secondary lines. The contractor shall take all precautions not to disturb or damage any underground utilities including gas, electric, water or sewer while performing underground work. Secondary duct bank shall be schedule 40 PVC. All road crossings and bends greater than 45 degrees shall be RGS. Secondary Trench shall be 24” deep.

16. The contractor shall coordinate with the customer and electric shop and deenergize the existing panels and provide and install new cables and conduits as shown on the dwg. The as-built dwgs. for the existing panels are not available.

17. Contractor shall test all new medium and low voltage cable furnished and installed under this contract and submit the test results to the contracting officer.

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18. The exposed conduit inside the building shall be EMT and all underground conduits shall be Schedule 40 PVC. Use only compression type connectors with EMT. The outdoor above ground conduits needed for outdoor equipment connections shall be RGS. Provide and install Schedule 80 PVC for road crossing and for all work underneath concrete.

19. Label all electrical equipment: Label all interior and exterior electrical equipment regarding what it feeds and/or how it is fed. Label all new manholes, transformers, PMS and all equipment supplied under this contract.

20. Test all equipment furnished under this contract and demonstrate their operation to the contracting officer.

21. Contractor shall submit the detailed progress schedule before the start of the work.

The schedule shall include but not limited to the time line for demolition of overhead

12.47 kV lines and associated poles, fabrication, testing and delivery of the new transformers, fabrication, testing and delivery of the new PMS, fuse cut out, installation of new duct bank, installation of the new cables in the duct banks, fabrication, delivery and installation of new manholes, installation of new concrete pad for transformer and PMS, testing of all materials, equipment supplied under this contract.

22. Submit shop drawings of all materials including but not limited to new transformer, new transformer certified test results, new PMS, new PMS certified test results, new duct banks, new man holes, new switch board, new breakers, new cables and conduits, new panels, new 15 KV Load break elbows, all materials supplied under this contract in AutoCAD 2009 or 2012 and pdf format. The contractor shall submit the O & M (Operation , Maintenance and Emergency Manuals) manuals for new transformer, new PMSs, new switchboard including breakers, protective relays, CT’s, etc…, new breakers, new panels, new multimeter and new energy meter.

Submit 5 hard copies. Also, submit As-built drawings in AutoCAD 2009 or 2012 and pdf format.

23. Upon notification of completion by the contractor a determination will be made as to the satisfactory completion and acceptance. Any segment of the operation that is not acceptable because of an unsightly or unprofessional appearance will be justification for rejection. The contractor will then incur all costs, both labor and materials, for re-accomplishment of any unacceptable work identified.

The contractor will be responsible for and incur any and all labor and material costs required to repair any damages to government that occurred during and as result of repair work, replacement operations, or new work, under this contract, including any damage caused by weather from failure to protect Work. This damage will be identified as separate from the condition of the equipment as identified during the

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initial inspection. The damage will be identified, but not limited, to the following items.

Government gas, water, drainage and electric transmission and distribution systems, Repairing damaged grass areas with new sod installed flush with existing lawn areas

Additional Information.

a. The contractor will begin work not earlier than 7:30 am each workday. Work will not be performed later than 6:00 pm.

b. Inspections will be conducted by the Contracting Officer and /or Contracting Officer’s Representative (COR) and the Contractor’s Manager.

c. Any discrepancies with provided documents should be noted and forwarded to the Base Engineer through the COR.

24. WARRANTY. Contractor/Manufacturer shall give minimum one (1) year warranty for all equipment and materials supplied under this contract. The warranty shall also include the labor, material supplied under this contract and contractor/manufacturer travel time.

25. The contractor shall make provision of 10% of contract price for contingency allowance for any unknown work, since accurate shop drawings of the facility are not available. The contractor shall request any unknown work to the contracting officer and get the approval from the contracting officer before the contractor can use the contingency allowance.

S&C Manual Vista® Underground Distribution Switchgear Outdoor Distribution (15.5 kV through 38 kV)

Specifications

1.0 GENERAL

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1.01 The switchgear shall be in accordance with the single-line diagram, and shall conform to the following specification.

1.02 The switchgear shall consist of a gas-tight tank containing SF6 gas, load-interrupter switches and resettable fault interrupters with visible open gaps and integral visible grounds, and a microprocessor-based overcurrent control. Load-interrupter switch terminals shall be equipped with bushings rated 600 amperes continuous, and fault-interrupter terminals shall be equipped with bushing wells rated 200 amperes continuous to provide for elbow connection. Manual operating mechanisms and viewing windows shall be located on the opposite side of the tank from the bushings and bushing wells, so that operating personnel shall not be required to perform any routine operations in close proximity to high-voltage elbows and cables. The new PMS shall be painted Barksdale Brown in color per Spec.

20117.

1.03 Ratings

The ratings for the integrated switchgear shall be as designated below. (Select values from the table on page 2.)

Frequency, Hz _________________ 60 Hz Short-Circuit Current, Amperes, RMS, Symmetrical _________________12,500 Amp Voltage Class, kV _________________15.5 KV Maximum Voltage, kV _________________15.5 KV BIL Voltage, kV _________________ 95 KV Main Bus Continuous Current, Amperes _________________600 AMP Three-Pole Load-Interrupter Switches Continuous Current, Amperes _________________ 600 Amp Load Dropping Current, Amperes _________________ 600 Amp Fault Closing Current, Duty-Cycle Three-Time, Amperes, RMS, Symmetrical _________________12,500 Amp Three-Time, Amperes, Peak _________________12,500 Amp Ten-Time, Amperes, RMS, Symmetrical _________________ 12,500 Amp Ten-Time, Amperes, Peak _________________ 32,500 Amp Fault Interrupters Continuous Current, Amperes _________________ 200 Amp Load Dropping Current, Amperes _________________ 200 Amp Fault Interrupting Current, Duty-Cycle Three-Time, Amperes, RMS, Symmetrical _________________ 12,500 Amp Ten-Time, Amperes, RMS, Symmetrical _________________ 12,500 Amp Fault Closing Current, Duty-Cycle Three-Time, Amperes, RMS, Symmetrical _________________ 12,500 Amp Three-Time, Amperes, Peak _________________ 32,500 Amp Ten-Time, Amperes, RMS, Symmetrical _________________ 12,500 Amp Ten-Time, Amperes, Peak _________________ 32,500 Amp

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1.04 Certification of Ratings

(a) The manufacturer of the switchgear shall be completely and solely responsible for the performance of the load-interrupter switch and fault interrupter as well as the complete integrated assembly as rated.

(b) The manufacturer shall furnish, upon request, certification of ratings of the load-interrupter switch, fault interrupter, and the integrated switchgear assembly consisting of switches and fault interrupters in combination with the gas-tight tank.

1.05 Compliance with Standards and Codes

The switchgear shall conform to or exceed the applicable requirements of the following standards and codes:

(a) The applicable portions of ANSI C57.12.28, covering enclosure integrity for pad-mounted equipment.

(b) The applicable portions of ANSI C37.71, ANSI C37.72, ANSI C37.73, IEC 56, and IEC 265-1 (Class A), which specify test procedures and sequences for the load-interrupter switches, fault interrupters, and the complete switchgear assembly.

2.0 CONSTRUCTION

2.01 SF6-Gas Insulation

(a) The SF6 gas shall conform to ASTM D2472.

(b) The switchgear shall be filled with SF6 gas to a pressure of 7 psig at 68º F.

(c) The gas-tight tank shall be evacuated prior to filling with SF6 gas to minimize moisture in the tank.

(d) The switchgear shall withstand system voltage at a gas pressure of 0 psig at 68º F.

(e) A gas-fill valve shall be provided.

(f) A temperature-compensated pressure gauge shall be provided that is color coded to show the operating range. The gauge shall be mounted inside the gas-tight tank (visible through a large viewing window) to provide consistent pressure readings regardless of the temperature or altitude at the installation site.

2.02 Gas-Tight Tank

(a) The tank shall be submersible and able to withstand up to 10 feet of water over the base.

(b) The tank shall be of welded construction and shall be made of Type 304L stainless steel, as specified in Section 4.0.

(c) A means of lifting the tank shall be provided.

2.03 Gas-Tight Tank Finish (for mild steel only)

(a) To remove oils and dirt, to form a chemically and anodically neutral conversion coating to improve the finish-to-metal bond, and to retard underfilm propagation of corrosion, mild-steel surfaces shall undergo a thorough pretreatment process comprised of a fully automated system of cleaning, rinsing, phosphatizing, sealing, drying, and cooling, before any protective coatings are applied. By utilizing an automated pretreatment process, the mild-

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steel surfaces of the gas-tight tank shall receive a highly consistent thorough treatment, eliminating fluctuations in reaction time, reaction temperature, and chemical concentrations.

(b) After pretreatment, protective coatings shall be applied that shall help resist corrosion and protect the mild-steel surfaces of the gas-tight tank. To establish the capability to resist corrosion and protect the mild steel, representative test specimens coated by the manufacturer's finishing system shall satisfactorily pass the following tests:

(1) 1500 hours of exposure to salt-spray testing per ASTM B 117 with:

(i) Underfilm corrosion not to extend more than 1/32 in. from the scribe, as evaluated per ASTM D 1645, Procedure A, Method 2 (scraping); and

(ii) Loss of adhesion from bare metal not to extend more than 1/8 in. from the scribe.

(2) 1000 hours of humidity testing per ASTM D 4585 using the Cleveland Condensing Type Humidity Cabinet, with no blistering as evaluated per ASTM D 714.

(3) Crosshatch-adhesion testing per ASTM D 3359 Method B, with no loss of finish.

Certified test abstracts substantiating the above capabilities shall be furnished upon request.

(c) The finish shall be inspected for scuffs and scratches. Blemishes shall be touched up by hand to restore the protective integrity of the finish.

(d) The finish shall be indoor light gray, satisfying the requirements of ANSI Standard Z55.1 for No. 61.

2.04 Viewing Windows

(a) Each load-interrupter switch shall be provided with a large viewing window at least 6 inches by 12 inches to allow visual verification of the switch-blade position (closed, open, and grounded) while shining a flashlight on the blades.

(b) Each fault interrupter shall be provided with a large viewing window at least 6 inches by 12 inches to allow visual verification of the disconnect-blade position (closed, open, and grounded) while shining a flashlight on the blades.

(c) Viewing windows shall be located on the opposite side of the gear from the bushings and bushing wells so that operating personnel shall not be required to perform any routine operations in close proximity to high-voltage elbows and cables.

(d) A cover shall be provided for each viewing window to prevent operating personnel from viewing the flash which may occur during switching operations.

2.05 High-Voltage Bus

(a) Bus and interconnections shall withstand the stresses associated with short-circuit cur-rents up through the maximum rating of the switchgear.

(b) Before installation of aluminum bus, all electrical contact surfaces shall first be pre-pared by machine-abrading to remove any oxide film. Immediately after this operation, the electrical contact surfaces shall be coated with a uniform coating of an oxide inhibitor and sealant.

2.06 Provisions for Grounding

(a) One ground-connection pad shall be provided on the gas-tight tank of the switchgear.

(b) The ground-connection pad shall be constructed of stainless steel and welded to the gas-tight tank, and shall have a short-circuit rating equal to that of the switchgear.

(c) When an enclosure is provided, no less than one enclosure ground pad shall be provided.

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(d) One ground-connection pad per way shall be provided.

2.07 Connections

(a) For gear rated 12.5 kA short circuit, load-interrupter switches shall be equipped with 600-ampere bushings, and fault interrupters shall be equipped with 200-ampere bushing wells.

(b) For gear rated 25 kA short circuit, load-interrupter switches and fault interrupters shall be equipped with 600- or 900-ampere bushings.

(c) Bushings and bushing wells shall be located on one side of the gear to reduce the required operating clearance.

The following optional feature should be specified as required:

(d) Bushings rated 600 amperes continuous shall be provided without a threaded stud.

For gear rated 12.5 kA only, the following optional features should be specified as required:

(e) Fault interrupters shall be equipped with 600-ampere bushings.

(f) Load-interrupter switches shall be equipped with 200-ampere bushing wells.

2.08 Bushings and Bushing Wells

(a) Bushings and bushing wells shall conform to ANSI/IEEE Standard 386.

(b) Bushings and bushing wells shall include a semiconductive coating.

(c) Bushings and bushing wells shall be mounted in such a way that the semiconductive coating is solidly grounded to the gas-tight tank.

3.0 BASIC COMPONENTS

3.01 Load-Interrupter Switches

(a) The three-phase, group-operated load-interrupter switches shall have a three-time and ten-time duty-cycle fault-closing rating as specified under "Ratings." This rating defines the ability to close the switch the designated number of times against a three-phase fault with asymmetrical (peak) current in at least one phase equal to the rated value, with the switch remaining operable and able to carry and interrupt rated current. Certified test abstracts establishing such ratings shall be furnished upon request.

(b) The switch shall be provided with an integral ground position that is readily visible through the viewing window to eliminate the need for cable handling and exposure to high voltage to ground the equipment.

(c) The ground position shall have a three-time and ten-time duty-cycle fault-closing rating.

(d) The switch shall be provided with an open position that is readily visible through the viewing window to eliminate the need for cable handling and exposure to high voltage to establish a visible gap.

(e) The open gaps of the switch shall be sized to allow cable testing through a feedthru bushing or the back of the elbow.

3.02 Fault Interrupters

(a) Fault interrupters shall have a three-time and ten-time duty-cycle fault-closing and fault interrupting rating as specified under "Ratings." This rating defines the fault interrupter's ability to close the designated number of times against a three-phase fault with asymmetrical

FA4608-15-R-0006

(peak) current in at least one phase equal to the rated value and clear the resulting fault current, with the interrupter remaining operable and able to carry and interrupt rated current.

Certified test abstracts establishing such ratings shall be furnished upon request.

(b) The fault interrupter shall be provided with a disconnect with an integral ground position that is readily visible through the viewing window to eliminate the need for cable handling and exposure to high voltage to ground the equipment.

(c) The ground position shall have a three-time and ten-time duty-cycle fault-closing rating.

(d) The disconnect shall be provided with an open position that is readily visible through the viewing window, eliminating the need for cable handling and exposure to high volt-age to establish a visible gap.

(e) The fault interrupter, including its three-position disconnect, shall be a single integrated design so that operation between the closed and open positions or the open and grounded positions is accomplished with a single, intuitive movement.

(f) The open gaps of the disconnect shall be sized to allow cable testing through a feedthru bushing or the back of the elbow.

(g) An internal indicator shall be provided for each fault interrupter to show when it is in the tripped condition. The indicator shall be clearly visible through the viewing window.

3.03 Operating Mechanisms

(a) Load-interrupter switches and fault interrupters shall be operated by means of a quick-make, quick-break mechanism.

(b) The manual handle shall charge the operating mechanism for closing, opening, and grounding of the switches and fault interrupters.

(c) A single, integrated operating mechanism shall fully operate each fault interrupter or load interrupter switch in a continuous movement, so that additional operations are not required to establish open or grounded positions.

(d) Operating mechanisms shall be equipped with an operation selector to prevent inadvertent operation from the closed position directly to the grounded position, or from the grounded position directly to the closed position. The operation selector shall require physical movement to the proper position to permit the next operation.

(e) Operating shafts shall be padlockable in any position to prevent operation.

(f) The operation selector shall be padlockable to prevent operation to the grounded position.

(g) The operating mechanism shall indicate switch position which shall be clearly visible from the normal operating position.

3.04 Overcurrent Control

(a) A microprocessor-based overcurrent control shall be provided to initiate fault interruption.

(b) For dry-vault-mounted style and pad-mounted style switchgear, the control shall be mounted in a watertight enclosure. For UnderCover style and wet-vault-mounted style switchgear, the control shall be mounted in a submersible enclosure. The control shall be removable in the field without taking the gear out of service.

(c) Control settings shall be field-programmable using a personal computer connected via a data port to the control. The data port shall be accessible from the exterior of the enclosure.

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Neither external power nor energization of the gear shall be required to set or alter control settings.

(d) Power and sensing for the control shall be supplied by integral current transformers.

(e) The minimum total clearing time (from initiation of the fault to total clearing) for fault interruption shall be 40 milliseconds (2.4 cycles) at 60 hertz or 44 milliseconds (2.2 cycles) at 50 hertz.

(f) The control shall feature time-current characteristic (TCC) curves including standard E speed, K-speed, coordinating-speed tap, coordinating-speed main, and relay curves per IEEE C37.112-1996. Coordinating-speed tap curves shall optimize coordination with load-side weak-link/backup current-limiting fuse combinations, and coordinating-speed main curves shall optimize coordination with tap-interrupter curves and upstream feeder breakers.

(g) The standard E-speed curve shall have phase-overcurrent settings ranging from 25E through 400E. The standard K-speed curve shall have phase-overcurrent settings ranging from 25K through 200K. The coordinating-speed tap curve shall have phase-overcurrent and independent ground-overcurrent settings ranging from 50 amperes through 400 amperes.

The coordinating-speed main curve shall have phase-overcurrent settings ranging from 100 amperes through 800 amperes and independent ground-overcurrent settings ranging from 100 amperes through 400 amperes.

(h) Time-current characteristic curves shall conform to the following IEEE C37.112-1996 IEEE Standard Inverse-Time Characteristic Equations for Overcurrent Relays: U.S.

Moderately Inverse Curve U1, U.S. Inverse Curve U2, U.S. Very Inverse Curve U3, U.S.

Extremely Inverse Curve U4, U.S. Short-Time Inverse Curve U5, I.E.C. Class A Curve (Standard Inverse) C1, I.E.C. Class B Curve (Very Inverse) C2, I.E.C. Class C Curve (Extremely Inverse) C3, I.E.C. Long-Time Inverse Curve C4, and I.E.C. Short-Time Inverse Curve C5.

(i) The control shall have field-adjustable instantaneous-trip settings (0.2 kA through 6 kA) and definite-time delay settings (32 ms through 96 ms for coordinating-speed tap and 64 ms through 128 ms for coordinating-speed main), to allow tailoring of the coordinating-speed tap and coordinating-speed main curves to the application.

(j) Event records shall be easily extractable from the control using a personal computer connected to the data port.

3.05 Voltage Indication

(a) Voltage indication

(1) Voltage indication shall be provided for each load-interrupter switch and fault interrupter by means of capacitive taps on the bushings, eliminating the need for cable handling and exposure to high voltage to test the cables for voltage prior to grounding. This feature shall include a flashing liquid-crystal display to indicate the presence of voltage for each phase, and a solar panel to supply power for testing of the complete voltage-indication circuit.

(2) The voltage-indication feature shall be mounted on the covers for the viewing windows, on the opposite side of the gear from the bushings and bushing wells, so that operating personnel shall not be required to perform any routine operations in close proximity to high-voltage elbows and cables.

(b) Voltage indication with provisions for low-voltage phasing

FA4608-15-R-0006

(1) Voltage indication with provisions for low-voltage phasing shall be provided for each load-interrupter switch and fault interrupter by means of capacitive taps on the bushings, eliminating the need for cable handling and exposure to high voltage to test the cables for voltage and phasing. This feature shall include a flashing liquid-crystal display to indicate the presence of voltage for each phase, and a solar panel to supply power for testing of the complete voltage-indication circuit and phasing circuit.

(2) The voltage-indication feature shall be mounted on the covers for the viewing windows, on the opposite side of the gear from the bushings and bushing wells, so that operating personnel shall not be required to perform any routine operations in close proximity to high-voltage elbows and cables.

4.0 SWITCHGEAR STYLE (pad-mounted style.)

4.01 Pad-Mounted Style

(a) The gas-tight tank shall be made of Type 304L stainless steel.

(b) To guard against corrosion, the gas-tight tank shall be made of Type 304L stainless steel.

(c) For gear rated 12.5 kA short circuit, the switchgear shall conform to or exceed the requirements of applicable portions of IEC 298, Appendix AA covering arc resistance, through 12.5 kA for 15 cycles.

(d) For gear rated 25 kA short circuit, the switchgear shall conform to or exceed the requirements of applicable portions of IEC 298, Appendix AA covering arc resistance, through 25 kA for 15 cycles.

(e) Enclosure

(1) The switchgear shall be provided with a pad-mounted enclosure suitable for installation of the gear on a concrete pad.

(2) The pad-mounted enclosure shall be separable from the switchgear to allow clear access to the bushings and bushing wells for cable termination.

(3) The basic material shall be 14-gauge hot-rolled, pickled and oiled steel sheet.

(4) The enclosure shall be provided with removable front and back panels, and hinged lift-up roof sections for access to the operating and termination compartments. Each roof section shall have a retainer to hold it in the open position.

(5) Lift-up roof sections shall overlap the panels and shall have provisions for pad-locking that incorporate a means to protect the padlock shackle from tampering.

(6) The base shall consist of continuous 90-degree flanges, turned inward and welded at the corners, for bolting to the concrete pad.

(7) Panel openings shall have 90-degree flanges, facing outward, that shall provide strength and rigidity as well as deep overlapping between panels and panel openings to guard against water entry.

(8) For bushings rated 600 amperes continuous, the termination compartment shall be of an adequate depth to accommodate encapsulated surge arresters mounted on 600-ampere elbows having 200-ampere interfaces.

(9) For bushing wells rated 200 amperes continuous, the termination compartment shall be of an adequate depth to accommodate 200-ampere elbows mounted on feedthru inserts.

(10) An instruction manual holder shall be provided.

(11) Non-removable lifting tabs shall be provided.

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The following optional feature should be specified as required:

(12) To guard against corrosion due to extremely harsh environmental conditions, the entire exterior of the enclosure shall be fabricated from Type 304 stainless steel.

(f) Enclosure Finish

(1) All exterior welded seams shall be filled and sanded smooth for neat appearance.

(2) To remove oils and dirt, to form a chemically and anodically neutral conversion coating to improve the finish-to-metal bond, and to retard underfilm propagation of corrosion, all surfaces shall undergo a thorough pretreatment process comprised of a fully automated system of cleaning, rinsing, phosphatizing, sealing, drying, and cooling, before any protective coatings are applied. By utilizing an automated pretreatment process, the enclosure shall receive a highly consistent thorough treatment, eliminating fluctuations in reaction time, reaction temperature, and chemical concentrations.

(3) After pretreatment, protective coatings shall be applied that shall help resist corrosion and protect the steel enclosure. To establish the capability to resist corrosion and protect the enclosure, representative test specimens coated by the manufacturer's finishing system shall satisfactorily pass the following tests:

(i) 4000 hours of exposure to salt-spray testing per ASTM B 117 with:

(a) Underfilm corrosion not to extend more than 1/32 in. from the scribe, as evaluated per ASTM D 1645, Procedure A, Method 2 (scraping); and

(b) Loss of adhesion from bare metal not to extend more than 1/8 in. from the scribe.

(ii) 1000 hours of humidity testing per ASTM D 4585 using the Cleveland Condensing Type Humidity Cabinet, with no blistering as evaluated per ASTM D 714.

(iii) 500 hours of accelerated weathering testing per ASTM G 53 using lamp UVB-313, with no chalking as evaluated per ASTM D 659, and no more than 10% reduction of gloss as evaluated per ASTM D 523.

(iv) Crosshatch-adhesion testing per ASTM D 3359 Method B, with no loss of finish.

(v) 160-inch-pound impact, followed by adhesion testing per ASTM D 2794, with no chipping or cracking.

(vi) 3000 cycles of abrasion testing per ASTM 4060, with no penetration to the substrate.

Certified test abstracts substantiating the above capabilities shall be furnished upon request.

(4) The finish shall be inspected for scuffs and scratches. Blemishes shall be touched up by hand to restore the protective integrity of the finish.

(5) The finish shall be olive green, Munsell 7GY3.29/1.5.

The following optional feature should be specified as required:

(6) The finish shall be outdoor light gray, satisfying the requirements of ANSI Standard Z55.1 for No. 70.

5.0 LABELING

5.01 Hazard-Alerting Signs

(a) The exterior of the pad-mounted enclosure (if furnished) shall be provided with "Warning-Keep Out-Hazardous Voltage Inside-Can Shock, Burn, or Cause Death" signs.

(b) Each unit of switchgear shall be provided with a "Danger-Hazardous Voltage-Failure to Follow These Instructions Will Likely Cause Shock, Burns, or Death" sign. The text shall further indicate that operating personnel must know and obey the employer's work rules, FA4608-15-R-0006 know the hazards involved, and use proper protective equipment and tools to work on this equipment.

(c) Each unit of switchgear shall be provided with a "Danger-Keep Away-Hazardous Voltage-Will Shock, Burn, or Cause Death" sign.

5.02 Nameplates, Ratings Labels, and Connection Diagrams

(a) Each unit of switchgear shall be provided with a nameplate indicating the manufacturer's name, catalog number, model number, date of manufacture, and serial number.

(b) Each unit of switchgear shall be provided with a ratings label indicating the following:

voltage rating; main bus continuous current rating; short-circuit rating; fault-interrupter ratings including interrupting and duty-cycle fault-closing; and load-interrupter switch ratings including duty-cycle fault-closing and short-time.

(c) Each unit of the switchgear shall have arc flash label.

6.0 ACCESSORIES

6.01 A USB cable kit shall be provided for connecting an overcurrent control to a user-furnished personal computer.

7.0 ANALYTICAL SERVICES

The following analytical services should be specified as required:

7.01 Short-Circuit Analysis

(a) The manufacturer shall provide a short-circuit analysis to determine the currents flowing in the electrical system under faulted conditions. Since expansion of an electrical system can result in increased available short-circuit current, the momentary and interrupting ratings of new and existing equipment on the system shall be checked to determine if the equipment can withstand the short-circuit energy. Fault contributions from utility sources, motors, and generators shall be taken into consideration. If applicable, results of the analysis shall be used to coordinate overcurrent protective devices and prepare an arc-flash hazard analysis of the system.

(b) Data used in the short-circuit analysis shall be presented in tabular format, and shall include the following information:

(1) Equipment identifications.

(2) Equipment ratings.

(3) Protective devices.

(4) Operating voltages.

(5) Calculated short-circuit currents.

(6) X/R ratios.

(c) A single-line diagram model of the system shall be prepared, and shall include the following information:

(1) Identification of each bus.

(2) Voltage at each bus.

(3) Maximum available…