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CORRESPONDENCE - RFP - 8192 ELECTRICAL SERVICES 2015 (40)
Utilities Work Order Form Official Purchasing Form Last updated 10/2017 WORK ORDER PURSUANT TO A MASTER AGREEMENT BETWEEN THE CITY OF FORT COLLINS AND INTERSTATE CONSTRUCTION SERVICES, INC. WORK ORDER NUMBER: I-WRF-2017-23 PROJECT TITLE: DWRF Dewatering Bldg Transformer & Switchboard Procurement ORIGINAL BID/RFP NUMBER & NAME: 8192, Electrical MASTER AGREEMENT EFFECTIVE DATE: February 1, 2016 ARCHITECT/ENGINEER: Carollo Engineering, Inc. OWNER’S REPRESENTATIVE: Eileen Dornfest WORK ORDER COMMENCEMENT DATE: December 1, 2017 WORK ORDER COMPLETION DATE: December 31, 2018 MAXIMUM FEE: (time and reimbursable direct costs): $73,495.00 PROJECT DESCRIPTION/SCOPE OF SERVICES: Purchase high voltage transformer and switchboard for the dewatering project. See the attached supporting documentation. Service Provider agrees to perform the services identified above and on the attached forms in accordance with the terms and conditions contained herein and in the Master Agreement between the parties. In the event of a conflict between or ambiguity in the terms of the Master Agreement and this Work Order (including the attached forms) the Master Agreement shall control. The attached forms consisting of One Hundred Sixty Two (162) pages are hereby accepted and incorporated herein, by this reference, and Notice to Proceed is hereby given after all parties have signed this document. SERVICE PROVIDER: Interstate Construction Services, Inc. By: Date: Name: Title: Page 1 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Joshua Barber Regional Manager November 22, 2017 Utilities Work Order Form Official Purchasing Form Last updated 10/2017 OWNER’S ACCEPTANCE & EXECUTION: This Work Order and the attached Contract Documents are hereby accepted and incorporated herein by this reference. ACCEPTANCE: Date: Eileen Dornfest, Special Project Manager REVIEWED: Date: Doug Clapp, Senior Buyer APPROVED AS TO FORM: Date: Name,City Attorney's Title (if greater than $1,000,000) ACCEPTANCE: Date: Jason Graham, Water Reclamation & Biosolids Division Manager ACCEPTANCE: Date: Carol Webb, Water Resources & Treatment Operations Manager ACCEPTANCE: Date: Kevin Gertig, Utilities Executive Director (if greater than $1,000,000) ACCEPTANCE: Date: Gerry Paul, Purchasing Director (if greater than $60,000) ACCEPTANCE: Date: Darin Atteberry, City Manager (if greater than $1,000,000) ATTEST: Date: City Clerk (if greater than $1,000,000) Page 2 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 November 22, 2017 November 22, 2017 November 24, 2017 November 27, 2017 November 27, 2017 Utilities Work Order Form Official Purchasing Form Last updated 10/2017 ATTACHMENT A WORK ORDER SCOPE OF SERVICES AND COST DETAIL Page 3 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Nick- Attached please find the attached bid for the switchboard. -Switchboard only - $21,004.09 -Start Up Test - $4,808.92 -Training - $3,028.86 -Estimated Shipping (Including GPS & Impact recorder) $5,500 - $7,000 - An extra year of warranty will be applied at no additional cost to the customer from Eaton equipment manufacturers for which Eaton is supplying site acceptance testing services (per Eaton or NETA work scopes only) and power system studies. These are the exceptions being made in this proposal. Section 26 24 14 1.07.C Note. Temporary heating equipment by others. 2.05.D.4.a.2 Exception. Filtered roof vents are not available. 2.05.D.4.a.3.a Exception. Rear doors are not available. 2.05.D.4.a.4.d Exception. Front to rear full depth lifting beams are not available. Lifting hoops on all four corners are provided. 2.05.A.3 Exception. Switchboard will be furnished per plans and specs. 2.06.B.3 Exception. MTW wire would be used. 2.06.B.4.a Exception. Fourteen No. 14 for potential and current transformers circuits will be used. 2.07.B.1.c Exception. Warning signs is not provided by Eaton. Page 4 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Project Info: Project: Drake Water Reclamation Facility, Fort Collins, Job #: #Ge-082217-58244 Bid Date: 08/22/17 Bid Time: 12:00 AM CDT Quoter: Mike Scaletta SC 4162 Quotation Type Quantity Description Unit or Lot# Unit Price Ext Price TO: Expiration Date: 09/21/17 INTERSTATES CONSTRUCTION SERVICES Attn:S Spaulding PO BOX 260 SIOUX CENTER, IA 51250-0260 Page : 1 of 1 Vendor We are pleased to present the following proposal: 0 Revision 2 - 11/16/17 Unit 0.000/EA 0.00 SWBD 1 EATON CO Per NEG# K8210822X7K1/0004 Unit 21,004.086/EA 21,004.09 See attached BOM & Drawings. Price includs dedicated truck. Start-Up 1 EATON CO Start Up to meet Switchboard Spec Unit 4,808.922/EA 4,808.92 Training 1 EATON CO Training per BOM Unit 3,028.856/EA 3,028.86 1.09.A 0 EATON CO Ship equipment to Project Site after successful Unit 0.000/EA 0.00 completetion of factory acceptance test - $2800.00 per at the factory. Does not include travel or lodging. From: (9) VAN METER INC. PHONE 712-252-2040 901 Cunningham Drive SIOUX CITY, IA 51106 Printed By: Mike Scaletta SC 4162 MIke Scaletta For complete Terms and Conditions go to: https://vanmeterinc.com/terms-conditions.html Spares and extra materials not included unless noted Acceptance of this quote constitutes agreement to Net 30 terms Notes Total 28,841.87 Page 5 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Attached please find the following: -CED Proposal # BRD9734247 for Pad Mount Transformer Only (Item Alt. A) - $ $24,803.23 -CED Proposal for Witness Test - $1,750.00 Estimated cost of Delivery/Handling/Storage (this includes a dedicated truck and GPS and impact recorder) will range from $6,000.00 - $7,500.00 Estimated cost of adding FOB Destination to shipment is an additional 2%. Extended warranty is offered at an additional 3% per year, for up to a maximum of 3 additional years. Some additional notes: - Nameplates are made in accordance to Nameplate B per IEEE Std C57.12.00. Caution and warning labels are defined per a different standard, and are available upon request. A Danger/High-Voltage label has been added to this BoM. An additional nameplate has also been added to the outside of the LV door. - Specifications outlined in Section 2.07, J, K, L will be included and/or meet client specs. CED has sent the O&M for this transformer (see attached). Page 6 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 1 of 10 This bid contains protected, proprietary and confidential material that constitutes either (1) trade secrets and (2) commercial or financial information, the disclosure of which would cause substantial competitive harm to Eaton. Consolidated Electrical Distributors, Inc. 2025 Sharp Point Dr. Fort Collins, CO 80525 Phone # (970) 484-4377 FAX# (970) 484-1147 Price Bid Pad Mount Transformer Job Name: Drake Water Reclamation Facility (DWRF) Date: October 26 2017 Customer Name: Interstates Construction Services Customer Contact: Stan Spaulding CED CONTACT: Richard Grill EMAIL: rgrill@cedfortcollins.com PHONE: (970) 484-4377 Page 7 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Proposal Number: BRD9734247 Date: October 26, 2017 Revision 01 Proposal Valid Through: November 21, 2017 Page 2 of 10 This bid contains protected, proprietary and confidential material that constitutes either (1) trade secrets and (2) commercial or financial information, the disclosure of which would cause substantial competitive harm to Eaton. Proposal Details Revisions: Rev01 | 10/27/2017: Added design with DOE 2016 equivalent efficiency, Item 1A. Item 1 is DOE 2010 efficiency equivalent. MFG Terms of Sale: FOB Plant - Freight Prepaid and Allowed Payment Terms: Net 30 Proposal Valid Through: November 21, 2017 Quoted lead-times are based on current factory loading and are subject to change. Lead-time: Shipment is based on receipt of all required order information at Cooper Power Systems. X and Y (where applicable) are defined in the Item Details for each line item on this proposal. *IF NO APPROVAL DRAWINGS ARE REQUIRED, lead-time is (X) weeks from receipt of complete order information. *IF APPROVAL DRAWINGS ARE REQUIRED, drawings will be sent (Y) weeks from receipt of complete order information. Scheduling into production will occur upon the receipt of approved drawings at Cooper Power Systems with a release to manufacture. The equipment will be scheduled at the lead-time in effect at the time of release to manufacture. (CAUTION: This timeline does NOT include time for customer review and approval of drawings.) We now offer complete services for all your power distribution and automation needs. We have the industry’s largest Electrical Power Equipment Manufacturer’s Service Team, which provides 24 hour service. We provide start-up and commissioning; power system analysis including Arc Flash, Harmonics and other studies; preventive maintenance, testing and field trouble-shooting; multi-year service contracts; power system automation engineering, monitoring and training; aftermarket life extension solutions; as well as turnkey project capabilities. In addition to the services that we can provide for the equipment contained within this proposal, our Service Team is experienced on all manufacturers' electrical power distribution equipment, so please contact us about any electrical system problem. If you need immediate service, you can contact the Representative who provided this proposal, or call our 24- hour response number: 1-800-498-2678. All 3 phase padmount transformers will be designed and manufactured in accordance with the latest revision of IEEE Standards C57.12.34 and C57.12.28. Spec Section: EXCEPTIONS/CLARIFICATIONS GENERAL CLARIFICATION: This proposal is based solely on SPECIFICATION #10474A10 (AUG 2017 - DRAFT), SECTION 26 12 20. EXCEPTION - PARAGRAPH 1.07: Exception to the requirements in this paragraph. EXCEPTION - PARAGRAPH 1.08: Section 26 05 00 not provided. Unable to determine compliance. EXCEPTION - PARAGRAPH 1.09: All requirements by other. CLARIFICATION - SECTION 1.11: Section 26 05 00 not provided. Unable to determine compliance. Refer to Proposal Notes for details on EPS standard 12/18 month warranty. Page 8 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Proposal Number: BRD9734247 Date: October 26, 2017 Revision 01 Proposal Valid Through: November 21, 2017 Page 3 of 10 This bid contains protected, proprietary and confidential material that constitutes either (1) trade secrets and (2) commercial or financial information, the disclosure of which would cause substantial competitive harm to Eaton. EXCEPTION - PARAGRAPH 1.12: System start-up by other. CLARIFICATION - PARAGRAPH 2.06.C.4: EPS transformers do not include a compartment hood. CLARIFICATION - PARAGRAPH 2.06.C.10.d: Bay-O-net fuses are not shown on the drawing and not included in the BOM. EXCEPTION - PART 3 EXECUTION: All requirements in this section by other. Page 9 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Proposal Number: BRD9734247 Date: October 26, 2017 Revision 01 Proposal Valid Through: November 21, 2017 Page 4 of 10 This bid contains protected, proprietary and confidential material that constitutes either (1) trade secrets and (2) commercial or financial information, the disclosure of which would cause substantial competitive harm to Eaton. Item Details Item Number: 00001 Customer RFQ Information: Specification: SPEC - DWRF Dewatering Project - September 2017; Dated: 9/1/2017 One-Line Diagram: ONE-LINE - DWRF Dewatering Project - September 2017; Dated: 9/1/2017 Quantity Unit Price Extended Price 1 $24474.20 USD $24474.20 USD Lead-time (Per Lead-time definition in Proposal Details): Product Lead-time (X): 11-13 weeks ex-factory Optional Approval Drawing Lead-time (Y): 4 weeks plus time for customer review. Description: kVA 1000 kVA 3 Phase Pad-Mounted Transformer Temperature Rise 65 degree average winding rise Cooling Class KNAN Frequency 60 Hz. Duty Cycle Designed for step-up operation Insulating fluid Envirotemp FR3 Elevation Designed for operation at 1000 m (3300 ft) above sea level Sound Level NEMA TR1 Standard Efficiency Requirement Meets Efficiency defined by DOE 2010 for the same kVA rating High Voltage 13200GY/7620 Volts, 95 kV BIL kV Class 15 kV High Voltage Configuration Dead Front, Loop Feed Taps [Non-Isolated] 2 - 2.5% taps above and 2 - 2.5% taps below nominal Tap Changer 100 Amp 5-position tap changer High Voltage Bushings 200 amp Cooper bushing wells with removable studs (Qty: 6) Inserts 15 kV, 95 kV BIL Cooper load-break inserts (Qty: 6) Neutral Bushing 5/8" copper stud with 4-hole screw-on spade bushing(s) Load-break Switching None High Voltage Arresters Varistar elbow arresters, 15 kV class, 10 kV (Qty: 3) Overcurrent Protection None Low Voltage 480Y/277 Volts, 30 kV BIL Low Voltage kV Class 1.2 kV Low Voltage Bushings 1" copper stud with 6-hole screw-on spade bushing(s) (Qty: 4) Cabinet 30 inch deep cabinet Cabinet hardware Penta-head cabinet door bolts IEEE K-Dimension Loop feed per IEEE C57.12.34-2015 Figure 16 specific dimensions (without bails) Coatings Munsell Green (Munsell 7GY 3.29/1.5) topcoat Gauges & Fittings Liquid level gauge Gauges & Fittings Thermometer, dial-type Gauges & Fittings Pressure/vacuum gauge Gauges & Fittings Schrader valve Gauges & Fittings Pressure relief device, 50 SCFM Gauges & Fittings Drain valve (1") with sampler in LV compartment Tank accessories Nitrogen Blanket Tank accessories IEEE standard two-hole ground pads (Qty: 3) Packaging Pallet Cover Welded cover with handhole Page 10 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Proposal Number: BRD9734247 Date: October 26, 2017 Revision 01 Proposal Valid Through: November 21, 2017 Page 5 of 10 This bid contains protected, proprietary and confidential material that constitutes either (1) trade secrets and (2) commercial or financial information, the disclosure of which would cause substantial competitive harm to Eaton. Item Number: 00001 LV and HV Cable Supports Add LV and HV cable supports PERFORMANCE DATA: Design Impedance No Load Losses @20 C Load Losses @85 C Efficiency @ 50% Load Efficiency @ 100% Load Exciting Current @ 100% Voltage Exciting Current @ 110% Voltage Percent IR (Resistance) Percent IX (Reactance) Fluid Weight Total Weight Fluid Volume Primary Conductor Material Secondary Conductor Material Estimated Overall Height Estimated Overall Width Estimated Overall Depth **Losses are For Reference Only** 5.73% (For Reference Only) 923 Watts 8353 Watts 99.44 % 99.08 % 0.20 % 0.35 % 0.85 % 5.67 % 2293 lbs 7761 lbs 299 Gallons Copper Copper 66.66 inches 80.49 inches 74.36 inches Page 11 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Proposal Number: BRD9734247 Date: October 26, 2017 Revision 01 Proposal Valid Through: November 21, 2017 Page 6 of 10 This bid contains protected, proprietary and confidential material that constitutes either (1) trade secrets and (2) commercial or financial information, the disclosure of which would cause substantial competitive harm to Eaton. Item Details Item Number: 00001 Item Alternate: A Customer RFQ Information: Specification: SPEC - DWRF Dewatering Project - September 2017; Dated: 9/1/2017 One-Line Diagram: ONE-LINE - DWRF Dewatering Project - September 2017; Dated: 9/1/2017 Quantity Unit Price Extended Price 1 $24803.23 USD $24803.23 USD Lead-time (Per Lead-time definition in Proposal Details): Product Lead-time (X): 11-13 weeks ex-factory Optional Approval Drawing Lead-time (Y): 4 weeks plus time for customer review. Description: kVA 1000 kVA 3 Phase Pad-Mounted Transformer Temperature Rise 65 degree average winding rise Cooling Class KNAN Frequency 60 Hz. Duty Cycle Designed for step-up operation Insulating fluid Envirotemp FR3 Elevation Designed for operation at 1000 m (3300 ft) above sea level Sound Level NEMA TR1 Standard Efficiency Requirement Meets Efficiency defined by DOE 2016 for the same kVA rating High Voltage 13200GY/7620 Volts, 95 kV BIL kV Class 15 kV High Voltage Configuration Dead Front, Loop Feed Taps 2 - 2.5% taps above and 2 - 2.5% taps below nominal Tap Changer 100 Amp 5-position tap changer High Voltage Bushings 200 amp Cooper bushing wells with removable studs (Qty: 6) Inserts 15 kV, 95 kV BIL Cooper load-break inserts (Qty: 6) Neutral Bushing 5/8" copper stud with 4-hole screw-on spade bushing(s) Load-break Switching None High Voltage Arresters Varistar elbow arresters, 15 kV class, 10 kV (Qty: 3) Overcurrent Protection None Low Voltage 480Y/277 Volts, 30 kV BIL Low Voltage kV Class 1.2 kV Low Voltage Bushings 1" copper stud with 6-hole screw-on spade bushing(s) (Qty: 4) Cabinet 30 inch deep cabinet Cabinet hardware Penta-head cabinet door bolts IEEE K-Dimension Loop feed per IEEE C57.12.34-2015 Figure 16 specific dimensions (without bails) Coatings Munsell Green (Munsell 7GY 3.29/1.5) topcoat Gauges & Fittings Liquid level gauge Gauges & Fittings Thermometer, dial-type Gauges & Fittings Pressure/vacuum gauge Gauges & Fittings Schrader valve Gauges & Fittings Pressure relief device, 50 SCFM Gauges & Fittings Drain valve (1") with sampler in LV compartment Tank accessories Nitrogen Blanket Tank accessories IEEE standard two-hole ground pads (Qty: 3) Packaging Pallet Cover Welded cover with handhole Page 12 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Proposal Number: BRD9734247 Date: October 26, 2017 Revision 01 Proposal Valid Through: November 21, 2017 Page 7 of 10 This bid contains protected, proprietary and confidential material that constitutes either (1) trade secrets and (2) commercial or financial information, the disclosure of which would cause substantial competitive harm to Eaton. Item Number: 00001 Item Alternate: A LV and HV Cable Supports Add LV and HV cable supports PERFORMANCE DATA: Design Impedance No Load Losses @20 C Load Losses @85 C Efficiency @ 50% Load Efficiency @ 100% Load Exciting Current @ 100% Voltage Exciting Current @ 110% Voltage Percent IR (Resistance) Percent IX (Reactance) Fluid Weight Total Weight Fluid Volume Primary Conductor Material Secondary Conductor Material Estimated Overall Height Estimated Overall Width Estimated Overall Depth **Losses are For Reference Only** 5.73% (For Reference Only) 915 Watts 8397 Watts 99.44 % 99.08 % 0.19 % 0.30 % 0.85 % 5.66 % 2337 lbs 7819 lbs 304 Gallons Copper Copper 66.66 inches 80.49 inches 74.86 inches Page 13 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Proposal Number: BRD9734247 Date: October 26, 2017 Revision 01 Proposal Valid Through: November 21, 2017 Page 8 of 10 This bid contains protected, proprietary and confidential material that constitutes either (1) trade secrets and (2) commercial or financial information, the disclosure of which would cause substantial competitive harm to Eaton. Proposal Notes Technical In addition to transformers, Eaton’s Cooper Power Systems also offers a wide range of vault and pad- mounted underground distribution switchgear for your sectionalizing, overcurrent protection and automation needs. Various product types are available to provide either fused or electronic resettable overcurrent protection, with under oil or vacuum switching. Switchgear is also available for applications such as reclosing, source transfer, grid intertie, and automatic feeder reconfiguration. Please contact your sales representative for additional information. Coatings and surface preparation system shall be Eaton's standard, which is in compliance with IEEE C57.12.28 performance requirements. First coating of metal parts shall be a high-build electro-coat formulation, applied with an electrostatic dip process, over a zinc phosphate pretreatment. Inside cabinet surfaces and tank front shall be light gray. The second coating, a urethane overcoat applied for exterior ultraviolet protection shall be applied to the external tank and cabinet surfaces. Total dry film paint thickness shall be an average of 3 mils. Unless specifically listed in the quoted transformer bill of material, the following items are not included in this proposal: elbows, elbow grounding kits, connectors, stand-offs, insulated bushing type parking stands (standoff bushings), insulated protective caps (bushing covers), insulated protective bushing well plugs, secondary terminating lugs, grounding lugs, anchor bolts, padlocks, key interlocks, hot sticks, pentahead wrenches. Please contact your Eaton sales representative for information on how to procure this equipment. Product/Design Testing Eaton performs the routine tests as defined in the current IEEE standards C57.12.00 and C57.12.90, which include: • Ratio, Polarity, and Phase Relation: Ensures correct winding ratios, phase shift, and tap voltages. Tested at a maximum of 100V. • Winding Resistance: Verifies the integrity of internal HV and LV connections; provides data for loss upgrade calculations. • Insulation Power Factor: This test verifies that vacuum processing has thoroughly dried the insulation system to required limits. Please note ECPS does not utilize Doble testing equipment. • Routine Impulse Tests: The most severe test, simulating a lightning surge. Applies one reduced wave and one full wave to verify the BIL rating. • Applied Potential: Applied to both high-voltage and low-voltage windings, this test stresses the entire insulation system to verify all live-to-ground clearances. • Induced Potential: 3.46 times normal plus 1000 volts for reduced neutral designs, twice normal voltage for full-neutral designs. • Loss Test: These design verification tests are conducted to ensure that guaranteed loss values are met and that test values are within design tolerances. Tests include no-load loss and excitation current along with impedance voltage and load loss. • Leak Test: Pressurizing the tank for approximately 4 to 6 hours to ensure a complete seal, with no weld or gasket leaks, to eliminate the possibility of moisture infiltration or oil oxidation. This proposal is based upon standard factory testing. These tests are the routine tests as defined by IEEE C57.12.00. Certified test reports can be provided at no additional charge, if requested. The following special tests, witness of tests, or inspections must be individually itemized and shown on the Purchase Order. Any additions of these items after the initial P.O. date will be 2X the cost of the test or inspection: Page 14 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Proposal Number: BRD9734247 Date: October 26, 2017 Revision 01 Proposal Valid Through: November 21, 2017 Page 9 of 10 This bid contains protected, proprietary and confidential material that constitutes either (1) trade secrets and (2) commercial or financial information, the disclosure of which would cause substantial competitive harm to Eaton. WITNESS / INSPECTION VISIT: Customer Witness of Routine Test/Final Inspect: $2000 USD per unit, +1 week Customer Final Inspection: $1500 USD per unit, +1 week Core and Coil Inspection: $1000 USD per unit, +1 week Photographic Record of Core/Coil/Tanking: $750 USD per unit Please note that only one unit of each catalog design may be witness tested, including identical designs of double-ended substations. TEST Prices are per unit (USD) Heat Run: $3000 /unit, +1 week Chopped Wave Impulse Test (HV only): $2500/unit Full & Reduced Wave Impulse Test (LV only*): $2500/unit Record of Impulse Oscillogram Waveforms: $500/unit Sound Test (per NEMA TR-1): $2500/unit, +1 week RIV Test: $2500/unit, +2 weeks Zero Sequence Impedance Test: $1000/unit 24 Hour Leak Test: $500/unit Insulation Resistance (Megger): $500/unit Dissolved Gas Analysis: $600/unit PCB Fluid Testing: $500/unit Fluid Dielectric Testing: $500/unit Detection of Sulfur Dioxide: $500/unit *Only available if LV BIL is 60 kV or higher Commercial This Proposal is based on our interpretation of any Specifications, Drawings, and/or other information provided to Cooper. Accuracy/Completeness is the sole responsibility of the Distributor, Contractor, and End User. If any Item/Service is not listed it is not included nor implied to be. All Items/Services not shown/listed will be the responsibility of the Distributor, Contractor, and End User to furnish/provide. A written Purchase Order must be received by the sales office that submitted this quote within 60 days of the date on the quote. The Purchase Order may be either Release for Manufacture or Hold for Approval Drawing Submittal. When the order is Hold for Approval Drawing Submittal, the Approval Drawings must be returned to the submitting sales office with a Release for Manufacture within 60 days of the original P.O. date. Should the Release for Manufacture arrive after the 60 days mentioned above, an escalation schedule be applied as follows: > 60 days = 2% total price escalation > 90 days = 3% total price escalation >120 days = 4% total price escalation >150 days = 5% total price escalation >180 days = Order cancelled with 20% cancellation fee AND Customer must enter new order against updated Proposal Upon order entry by Eaton, the transformer will be acknowledged to ship at the quoted lead time or the best available lead time. Page 15 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Proposal Number: BRD9734247 Date: October 26, 2017 Revision 01 Proposal Valid Through: November 21, 2017 Page 10 of 10 This bid contains protected, proprietary and confidential material that constitutes either (1) trade secrets and (2) commercial or financial information, the disclosure of which would cause substantial competitive harm to Eaton. In the event Buyer cancels this agreement after award, the following will be charged as a percentage of the order price of each item cancelled: After award, before engineering has begun: 20%. After engineering has begun, before production firm schedule date: 50%. After production firm schedule date, before fabrication: 70%. After fabrication has begun: 100% For a fee of $1500 per design, Eaton will provide approval drawings prior to placement of a purchase order for the quoted units. This fee can then be applied toward the future purchase of the quoted units. For more information, please contact your Eaton Sales Representative. Approval drawing lead-time is 3- 4 weeks. Eaton’s standard limited warranty covers any defect which shall appear under proper and normal use of its equipment within one (1) year after date of shipment or within one (1) year after installation of the equipment, but not exceeding eighteen (18) months from date of shipment. For three phase pad mounted transformers, please reference installation and maintenance instructions document MN202001EN for preventative maintenance instructions to maintain the warranty period. Lead times quoted are based on accurate and complete information from the customer. If additional information or clarifications are required, a delayed response from the customer may affect the ship date(s) of the unit(s). The manufacturer cannot be held accountable for such delays. Page 16 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 COOPER POWER SERIES Distribution Transformers MN202001EN Effective August 2015 Supersedes S210-12-1 August 2013 Three-phase pad-mounted compartmental type transformer installation and maintenance instructions Page 17 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 DISCLAIMER OF WARRANTIES AND LIMITATION OF LIABILITY The information, recommendations, descriptions and safety notations in this document are based on Eaton Corporation’s (“Eaton”) experience and judgment and may not cover all contingencies. If further information is required, an Eaton sales office should be consulted. Sale of the product shown in this literature is subject to the terms and conditions outlined in appropriate Eaton selling policies or other contractual agreement between Eaton and the purchaser. THERE ARE NO UNDERSTANDINGS, AGREEMENTS, WARRANTIES, EXPRESSED OR IMPLIED, INCLUDING WARRANTIES OF FITNESS FOR A PARTICULAR PURPOSE OR MERCHANTABILITY, OTHER THAN THOSE SPECIFICALLY SET OUT IN ANY EXISTING CONTRACT BETWEEN THE PARTIES. ANY SUCH CONTRACT STATES THE ENTIRE OBLIGATION OF EATON. THE CONTENTS OF THIS DOCUMENT SHALL NOT BECOME PART OF OR MODIFY ANY CONTRACT BETWEEN THE PARTIES. In no event will Eaton be responsible to the purchaser or user in contract, in tort (including negligence), strict liability or other- wise for any special, indirect, incidental or consequential damage or loss whatsoever, including but not limited to damage or loss of use of equipment, plant or power system, cost of capital, loss of power, additional expenses in the use of existing power facilities, or claims against the purchaser or user by its customers resulting from the use of the information, recom- mendations and descriptions contained herein. The information contained in this manual is subject to change without notice. ii Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 18 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Contents SAFETY INFORMATION Safety Information .............................................................................iv PRODUCT INFORMATION Introduction ...................................................................................1 Acceptance and Initial Inspection...................................................................1 Handling ......................................................................................1 Storage .......................................................................................2 INSTALLATION INSTRUCTIONS Installation Location .............................................................................2 Mounting the Transformer ........................................................................2 Pre-Service Inspection (Exterior) ...................................................................2 Pre-Service Inspection (Interior) ....................................................................3 External Connections ............................................................................4 ACCESSORIES Liquid Level Gauge .............................................................................5 Liquid Temperature Gauge ........................................................................5 Pressure-Vacuum Gauge .........................................................................6 Pressure Relief Device ...........................................................................6 SWITCHES AND PROTECTIVE DEVICES Bay-O-Net Fuse. ................................................................................7 Internal Cartridge Fuse ..........................................................................10 Internal Loadbreak Switches ..................................................................... 11 Tap-Changer ..................................................................................12 Dual-Voltage and Delta-Wye Switch................................................................14 Vacuum Fault Interrupter (VFI) ....................................................................15 Air Switches (Arc Strangler™) ....................................................................16 Surge Arresters ...............................................................................17 MAINTENANCE Exterior Maintenance ...........................................................................19 Cabinet Interior Maintenance.....................................................................19 Tank Internal Maintenance .......................................................................19 Tank Cover Removal and Installation ...............................................................19 Bushing Removal and Replacement................................................................22 Cabinet Removal and Installation ..................................................................22 Insulating Liquid Maintenance ....................................................................23 OPERATION Operation ....................................................................................24 APPLICABLE STANDARDS Applicable Standards ...........................................................................25 SPARE PARTS AND SERVICE Spare Parts and Service .........................................................................25 PREVENTATIVE MAINTENANCE INSTRUCTIONS Preventative Maintenance Instructions .............................................................26 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 iii Page 19 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 iv Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001ENEN August 2015 The instructions in this manual are not intended as a substitute for proper training or adequate experience in the safe operation of the equipment described. Only competent technicians who are familiar with this equipment should install, operate, and service it. A competent technician has these qualifications: • Is thoroughly familiar with these instructions. • Is trained in industry-accepted high and low-voltage safe operating practices and procedures. • Is trained and authorized to energize, de-energize, clear, and ground power distribution equipment. • Is trained in the care and use of protective equipment such as arc flash clothing, safety glasses, face shield, hard hat, rubber gloves, clampstick, hotstick, etc. Following is important safety information. For safe installation and operation of this equipment, be sure to read and understand all cautions and warnings. Safety instructions Following are general caution and warning statements that apply to this equipment. Additional statements, related to specific tasks and procedures, are located throughout the manual. Safety for life ! SAFETY FOR LIFE ! SAFETY FOR LIFE Eaton meets or exceeds all applicable industry standards relating to product safety in its Cooper Power™ series products. We actively promote safe practices in the use and maintenance of our products through our service literature, instructional training programs, and the continuous efforts of all Eaton employees involved in product design, manufacture, marketing, and service. We strongly urge that you always follow all locally approved safety procedures and safety instructions when working around high voltage lines and equipment, and support our “Safety For Life” mission. Safety information DANGER Hazardous voltage. Contact with hazardous voltage will cause death or severe personal injury. Follow all locally approved safety procedures when working around high- and low-voltage lines and equipment. G103.3 WARNING Before installing, operating, maintaining, or testing this equipment, carefully read and understand the contents of this manual. Improper operation, handling or maintenance can result in death, severe personal injury, and equipment damage. G101.0 WARNING This equipment is not intended to protect human life. Follow all locally approved procedures and safety practices when installing or operating this equipment. Failure to comply can result in death, severe personal injury and equipment damage. G102.1 WARNING Power distribution and transmission equipment must be properly selected for the intended application. It must be installed and serviced by competent personnel who have been trained and understand proper safety procedures. These instructions are written for such Introduction Eaton provides installation and maintenance instructions for its Cooper Power™ series transformers in Service Information MN202001EN. These transformers are designed for installation on three-phase underground systems. All units are constructed for weather-exposed mounting on a concrete pad with high- and low-voltage cable entering the operating compartments through an opening in the pad. Read this manual first Read and understand the contents of this manual and follow all locally approved procedures and safety practices before installing or operating this equipment. Additional information These instructions are not intended to cover all details or variations in the equipment, procedures, or process described, nor to provide directions for meeting every possible contingency during installation, operation, or maintenance. For additional information, contact your Eaton representative. Acceptance and initial inspection Receiving Inspection It is important that a thorough inspection of the transformer be made before it is unloaded from the carrier. 1. Ensure that all parts listed on the bill of lading are present. 2. Before unloading the transformer, inspect for signs of damage or mishandling. Locate accessory parts that may have been shipped separately. 3. If damage is detected or shortages are noticed, write a brief description on the freight bill. Normally, the transformer is shipped FOB point of manufacture, and it is the customer’s responsibility to file a claim against the carrier. If the transformer was shipped FOB destination, notify your Eaton representative. He or she will, with the inspector’s report, take the necessary steps to file a claim against the carrier. Handling Special procedures must be followed when handling transformer in ambient temperatures below -20 °C. Contact your Eaton representative for further instructions. Failure to follow special handling procedures may cause premature failure of transformer and its components. Transformer weight The transformer weight is shown on the transformer nameplate. Most of the weight in a pad-mounted transformer assembly is in the main tank that holds the core and coil assembly and the insulating liquid. Moving transformers shipped on pallets Transformers shipped on pallets may be lifted or moved by forklift trucks of proper capacity. When using a forklift, lift with the transformer tank closest to the mast of the forklift since most of the transformer weight is in the tank. Pallet- mounted equipment may also be moved by crane or hoist. Lifting transformers by crane or hoist Check the weight of the transformer and the capacity and condition of all hoisting or lifting equipment. Do not use worn, frayed or damaged cables or slings. Do not use hoisting machinery with load capacity less than the weight of the transformer. Improper use of hoist or jack could seriously damage the transformer or its attachments or cause serious personal injury. For unloading, lifting lugs are provided near the top of the Storage Transformers that will not be placed in service immediately should be stored with terminal compartment doors closed and sealed to prevent damage to bushings or other attachments. Quality standards ISO 9001 certified quality management system Installation Installation location The transformer must be located to meet applicable fire codes. For indoor installations, the installation location must meet the requirements of the National Electrical Code (NEC®) with sufficient space requirements and proper over- current protection as specified by the listing body that has jurisdiction over the installation. These pad-mounted transformers are built to operate at altitudes up to 3300 feet at 30 °C average and 40 °C maximum ambient, unless otherwise specified. Before operating a standard transformer at higher altitudes, contact your Eaton representative. Mounting the transformer The transformer should be mounted on a level concrete pad. The pad should be strong enough to support the weight of the transformer. The site must be adequately prepared to prevent the transformer from tilting beyond two degrees from horizontal. Tilting beyond two degrees may cause internal components to come out of the oil and/or cables to mechanically stress the bushings and bushing gaskets. Excessive tilt (beyond two degrees) can result in a lower dielectric strength for the transformer than the basic insulation level (BIL) listed on the nameplate. Reduced BIL can result in an internal dielectric breakdown with a risk of explosion, tank rupture, or fire. To maintain full cabinet security, the transformer tank and cabinet base have provisions for installing cleats to secure transformer to pad. If gaps still exist between the cabinet and pad after cleating the cabinet, the installation will not provide the security needed to prevent tampering by the public. Add a permanent mortar seal to fill the gaps. Pre-service inspection (exterior) New transformers, or transformers which are being activated after a period of storage, should be thoroughly inspected before being connected to the power distribution system to identify damage which may have occurred during storage. 1. The transformer exterior should be inspected for nicks, dents, and scratches. Repair damage to weather- resistant finishes promptly. 2. The tank cover and manhole/handhole cover seals and all gaskets or seals at bushings, gauges, fuses, operating devices, etc., should be inspected for evidence of insulating liquid seepage. Repair leaking or improperly tightened gaskets and seals before the transformer is placed in service. 3. Under normal conditions, the transformer leaves the factory with a slight positive pressure in the tank over the oil. However, due to changes in atmospheric conditions, the unit may arrive under vacuum (negative pressure). This is itself is not cause for concern, however continued absence of either negative or positive 4. The liquid level inside the tank must be checked (see Insulating Liquid Maintenance section of this manual). On transformers equipped with a liquid level gauge, the liquid level may be read directly from the gauge. On transformers that are not gauge equipped, the tank liquid level must be determined by removing the liquid level plug (see Figure 2). At 25 °C liquid temperature, the liquid level should be at the bottom edge of the liquid level plug hole. If the tank temperature is greater than ambient air tem- perature, the transformer tank must be vented to zero pressure before the liquid level plug is removed. Failure to do so may cause hot oil to be sprayed from the plug hole and may result in severe personal injury. 5. Special procedures must be followed when energizing a transformer in ambient temperatures below -20 °C. Contact your Eaton representative for further instructions. Failure to follow special start- up procedures may cause premature failure of the transformer and its components. Also, note warning and caution statements in Switches and Protective Devices section of this manual for further precautions when operating under-oil loadbreak accessories in insulating liquid temperatures below 0 °C. Pre-service inspection (interior) Pre-service interior inspection may not be required if exterior inspection reveals no evidence of damage. If interior inspection is required, the transformer must be opened by removing the manhole/handhole or tank cover. See the Tank Cover Removal and Installation section of this manual. Pre-service interior inspections should be restricted to noting defects or damage that may prevent proper operation of the transformer. Inspect for: 1. Moisture on underside of the tank cover or man-hole cover. 2. Loose, shifted, or damaged parts (bushings, fuse holders, etc.). 3. Broken or loose connections. 4. Contaminated insulating liquid (sediment or foreign objects on the tank bottom, dirt or air bubbles suspended in the liquid). Internal damage If concealed internal damage is suspected, it may be necessary to lower the insulting liquid level to complete the inspection. Refer to the Insulating Liquid Maintenance section of this manual. Contaminated insulating liquid If moisture is found inside the tank, or there is evidence that the insulating liquid may be otherwise contaminated, a liquid sample should be taken for analysis. Samples should be drawn from the bottom of the tank. For instruction on sampling the insulating liquid please see the Insulating Liquid Maintenance section of this manual. If moisture is present in the liquid, the transformer must be dried out. Contact your Eaton representative for special instructions on dry-out or other decontamination processes. CAUTION Elevated Pressure. Can cause severe personal injury. External connections Transformers that require no internal inspection or repair may be connected to the system. Transformers must be connected and operated as indicated by the transformer nameplate. Clean bushings and terminals before making connections. Remove dirt, grease or foreign material. Contamination can cause failure of the bushings. Cables connected to the transformer terminals are to have sufficient flex to allow normal pad movement due to ground freeze/thaw and settling. Insufficient cable flex may cause premature failure of the bushings. Ground connections The transformer tank must be connected to a permanent, low-resistance ground. If the tank is not solidly grounded and the transformer is connected to the power distribution system, then the tank should be regarded as energized. An energized tank is extremely dangerous. Contact with an energized tank can shock, burn, or cause death. Three-phase pad-mounted transformers are equipped with two grounding pads for making the ground connection. The pads (see Figure 3) are located on the faceplate of the transformer behind the terminal compartment doors. One pad is in the primary compartment and the other in the secondary compartment. Grounded wye-grounded wye transformer connections Grounded wye-grounded wye winding connection transformers are designed for power distribution systems that have a grounded neutral connector. All windings designed for grounded neutral operation must be permanently and solidly grounded to the system neutral without electrical resistance. High voltage connections Make connections as shown in the diagrams and information on the transformer nameplate. Transformer neutrals must be connected to system neutrals. Leads and connections that are not used must be insulated from ground and all other leads. Livefront transformer connections Externally clamped porcelain bushings are normally provided for high voltage connection to three-phase pad-mounted livefront transformers. The bushings have tin-plated eyebolt terminals suitable for both copper and aluminum conductors. The bushings are positioned to allow vertical takeoff of primary cables entering from below. Deadfront transformer connections Deadfront three-phase pad-mounted transformers are equipped with universal bushing wells, one-piece bushings, or bushing wells with factory-installed inserts. Universal bushing wells must be field equipped with bushing well inserts before loadbreak cable connections can be made. Bushing well inserts must be compatible with the universal bushing well. Use of improperly rated inserts can cause premature failure of the transformer or its components. Read the manufacturer’s instructions furnished with the inserts before installing to determine if they are compatible. Low voltage connections Spade terminals are the standard low voltage connectors used for three-phase pad-mounted transformers. The low voltage bushings are externally clamped to the transformer Accessories Three-phase pad-mounted transformers can be equipped with a variety of optional equipment. Most such accessories are factory installed and no fieldwork is required to prepare them for operation. Liquid level gauge Transformers may be furnished with a liquid level indicator as optional equipment to aid in the systematic inspection of the transformer under load. It consists of a float-arm inside the tank, an indicating pointer and a magnetic coupling between the two across a liquid-tight separation. The gauge may have one or two SPDT (Single Pole Double Throw) alarm contacts to give a remote annunciation of low liquid level. For wiring and contact ratings, refer to the schematic furnished with the transformer. Liquid temperature gauge Transformers may be furnished with a temperature gauge as optional equipment to indicate the top liquid temperature in the tank in degrees Celsius. The temperature-sensitive element is mounted in a leak-proof well, permitting removal of the thermometer without lowering the oil level. The device is furnished with an additional red pointer to show the highest temperature attained since the last reset. To reset the maximum indicator, turn the knob in the center of the dial. The thermometer may have two SPDT contacts for energizing a fan circuit or for a high temperature alarm. For wiring and contact ratings, refer to the schematic furnished with the transformer. Figure 4. Liquid level gauge. Figure 5. Liquid temperature gauge. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 5 Page 25 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Pressure-vacuum gauge Transformers may be furnished with a pressure-vacuum gauge as optional equipment to indicate whether the gas space in the tank is under positive or negative pressure. The pressure will vary depending on the transformer temperature. If the transformer is de-energized or operating under light load in low ambients, the pressure may be negative. If sufficient air has been absorbed by the liquid during shipment or storage, the transformer may operate indefinitely in the vacuum range, depending upon the loading conditions. This, in itself, is not cause for concern, provided the pressure vacuum gauge does not remain on zero for any length of time - an indication of a leak. The transformer can safely operate in pressures ranging from -2 to +6 psig. The transformer may have pressure vacuum switches with two SPDT contacts for remote alarm on positive and negative pressure. For wiring and contact ratings, refer to the schematic furnished with the transformer. Pressure relief device Transformers may have a cover-mounted pressure relief device (PRD) in addition to the faceplate-mounted pressure relief valve (PRV) standard on all three-phase pad- mounted designs. The cover-mounted PRD consists of a self-resetting, spring-loaded diaphragm and a mechanical operation indicator. Should the tank pressure increase above that for which the device is set, the gas pressure will lift the diaphragm and let the gas escape quickly. Immediately after the pressure returns to normal, the diaphragm will reset and reseal the transformer. A mechanical indicator will protrude vertically. This must be reset manually to indicate subsequent operations. The PRD may have SPDT alarm contacts for remote signaling of device activation. For wiring and contact ratings, refer to the schematic furnished with the transformer. Figure 6. Pressure-vacuum gauge. Figure 7. Pressure relief device. CAUTION If the indicator reads zero and does not change under any load condition, the transformer should be checked for a possible leak in the seal. 6 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 26 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Switches and protective devices Bay-O-Net fuse Eaton’s Cooper Power series Bay-O-Net fuse assemblies are used to protect transformers and distribution systems. The assemblies are mounted on the faceplate of pad-mounted transformers and combine the ease of hotstick operation with the safety of deadfront construction (see Figure 8). WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. • Do not operate loadbreak equipment if a fault condition is suspected. Doing so can cause an explosion or fire. • Use a hotstick to operate transformer loadbreak equipment. • After operating transformer loadbreak equipment, check that voltages at transformer terminals are the expected values. Checking voltages verifies that loadbreak equipment operated properly and that electrical circuit conditions are as expected. • Before servicing transformer secondary connected equipment, verify that all transformer secondary terminals have zero voltage and ground the transformer secondary terminals following industry accepted safe grounding practices. Grounding secondary terminals protects against situations such as a standby generator energizing transformer from the secondary circuit. • Before servicing transformer, ALWAYS de-energize the transformer from a remote upstream source and then proceed to ground all primary and secondary transformer terminals following industry accepted safe grounding practices. Grounding secondary terminals protects against situations such as a standby generator energizing transformer from the secondary circuit. • Follow industry accepted safety practices. Utilize protective clothing and equipment when working with loadbreak equipment. WARNING Three-phase pad-mounted transformers use conventional transformer oil, R-Temp fluid, or Envirotemp™ FR3™ fluid for an insulating liquid. When the insulating liquid temperature is less than -20 °C (-4 °F) for conventional transformer oil, less than 0 °C (32 °F) for R-Temp fluid, or less than -10 °C (14 °F) for Envirotemp™ FR3™ fluid, viscosity is reduced, which may reduce make and break capabilities of loadbreak devices. Below these temperatures, under-oil loadbreak accessories should not be used to make or break a load. Instead, de-energize transformer from a remote upstream source before operating under-oil loadbreak devices. WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. Use a hotstick to service a Bay- O-Net fuse. Do not install a Bay-O-Net fuse to complete an electrical circuit if a fault condition is suspected. Do not re-energize suspected failed equipment. After installing Bay-O-Net fuse, energize transformer from a A Bay-O-Net fuse is not recommended for fault closing. Do not re-energize suspected failed equipment; serious personal injury may result. Internal fault conditions can cause the transformer to rupture or the cover to blow off. Always energize transformer from a remote upstream source. When replacing a blown fuse, the feed circuit should be opened and closed from a remote location. The Bay-O-Net fuse should be replaced using the procedure described below and re-energized from a remote upstream source. If equipment is re-fused while energized, the fuse could close in on the system’s maximum fault current. Any equipment that has a suspected failure should not be closed in with the fuse. For additional information on Eaton’s Cooper Power series Bay-O-Net fuse assembly, including loadbreak ratings, refer to catalog section CA132015EN, Service Information MN132003EN, and Service Information MN132002EN. Current sensing, dual sensing, dual element, and high ampere overload links can be used in a Bay-O-Net fuse assembly. For additional information on these links, including interrupting ratings, see catalog sections CA132009EN, CA132010EN, CA132011EN, and CA132007EN respectively. Bay-O-Net fuse re-fusing instructions Remove fuse holder Step 1 - Relieve tank pressure. Use a hotstick to perform the following steps: 1. Pull ring on pressure relief valve to open valve. Hold the valve open for 30 seconds after pressurized air can no longer be heard hissing through the valve. 2. Close pressure relief valve and wait 30 seconds. 3. Pull pressure relief valve open. Hold the valve open until hissing stops, and then for another 5 seconds. Pulling the valve open again allows any residual pressure to be released from tank. Step 2 - Unlock fuseholder and break seal. Use a hotstick to perform the following steps: 1. Stand to one side of the Bay-O-Net being removed. 2. Attach hotstick to fuseholder eye. 3. Twist hotstick to unlock fuseholder (see Figure 9). 4. Turn fuseholder 90° in the Bay-O-Net housing to break seal between seal gasket and Bay-O-Net housing (see Figure 10). Step 3 - Draw fuseholder out. Use a hotstick to perform the following steps: 1. Draw fuseholder out quickly 8 to 10 inches to interrupt load (see Figure 10). 2. Wait several seconds for fluid to drain from fuseholder. Step 4 - Remove fuseholder from Bay-O-Net housing. 1. Remove fuseholder from Bay-O-Net housing. 2. Wipe off fuse cartridge holder and fuse cartridge (see Figure 11). Figure 9. Unlock and turn fuseholder 90° in the Bay-O- Net CAUTION housing. If tank pressure has not been released, the fuse holder may be forced out of the Bay-O-Net housing. Maintain control of fuse holder at all times. CAUTION If fluid is coming out of the Bay-O-Net assembly, open the pressure relief valve again to equalize pressure Replace fuse link A separate replaceable fuse link, fuse cartridge, and end plug are available for all Eaton Bay-O-Net fuses except catalog numbers 4000358C16CB and C18CB, 4038361C03CB, C04CB, C05CB, and solid link 4038361C10CB. These catalog numbers are integral assembles which include the link, cartridge and end plug. For the above listed integral assemblies follow Step 5 and then tighten new cartridge/fuse/end plug against fuse holder using 50 to 70 in-lbs. torque; then, proceed to Step 9. For all other Bay-O-Net fuses, follow Steps 5 through 9. Step 5 - Remove fuse cartridge. Use a 3/4 inch wrench to remove fuse cartridge from fuse cartridge holder (see Figure 12). Step 6 - Remove end plug and fuse link from fuse cartridge. 1. Use 3/4 inch and 1/2 inch wrenches to remove end plug (see Figure 13). 2. Use screwdriver or other tool to straighten tulip tip end of fuse link and push fuse link out of fuse cartridge. Replace fuse cartridge if damaged. Step 7 - Insert replacement fuse link into fuse cartridge (see Figure 14). 1. A slight resistance may occur when inserting fuse link into cartridge. 2. If the catalog number of the fuse being replaced is not known, consult specifications or contact your Eaton representative. Fuse catalog numbers may also be indicated on the transformer door and/or nameplate. Figure 10. Draw fuseholder out 8 to 10 inches. Figure 11. Remove fuseholder from Bay-O-Net housing and wipe clean. Figure 12. Remove fuse cartridge holder. Figure 13. Remove end plug from fuse cartridge. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 9 Page 29 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Step 8 - Tighten cartridge to fuse cartridge holder. 1. Tighten fuse contact flare end against fuse cartridge holder using 50 to 70 in-lbs. torque. 2. Replace end plug on the other end of fuse cartridge and tighten to 50 to 70 in-lbs. torque. 3. Remove end plug and ensure that petals of tulip tip have spread uniformly. 4. Replace end plugs, applying 50 to 70 in-lbs. torque to both connections. Step 9 - Install fuse holder. Use a hotstick to perform the following steps. 1. Pull pressure relief valve, holding it open until hissing stops, and then for another five seconds. 2. Attach end of fuseholder assembly to hotstick and insert holder assembly firmly into Bay-O-Net housing. 3. Twist locking handle so that latch engages Bay-O-Net housing’s shoulder, and steel washer seats tightly on end of tube of Bay-O-Net holder assembly. Internal cartridge fuse Internal cartridge fuses are “weak link” expulsion-type fuses used to protect transformers and distribution systems. Internal cartridge fuse assemblies are mounted inside the transformer tank and are compatible for use in many insulating liquids. See fuse manufacturer’s product literature for maximum interrupting ratings. Internal cartridge fuse replacement 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals. 2. Remove tank cover as outlined in Tank Cover Removal and Installation section of this manual. 3. Locate cartridge fuse assembly (see Figure 15) on back tank wall. 4. Carefully remove all nuts that attach wire leads to fuse, making sure not to drop nuts into the transformer tank. Note position of all nuts, flat washers, spring washers, etc., so that they can be reinstalled in the same locations. 5. Replace fuses as required. Reconnect leads and re- install washers and nuts in original locations. 6. Re-install cover as outlined in Tank Cover Removal and Installation section of this manual. Figure 14. Insert replacement fuse link. Figure 15. Cartridge fuse assembly. CAUTION Visually inspect entire fuseholder assembly to ensure it is installed properly. WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. Turn off power to transformer before servicing internal cartridge fuses. Ground transformer following industry accepted safe grounding practices. 10 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 30 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Internal loadbreak switches It is recommended that remote energization be used whenever possible. Operate loadbreak switches using hotstick tool. After loadbreak switch is switched to “OPEN” position, verify that transformer secondary terminals have zero voltage and then ground the secondary terminals to prevent transformer backfeed energization. Two-position loadbreak switch The operating mechanism of the Eaton’s Cooper Power series two-position loadbreak switch employs a manually- charged over-toggle stored spring assembly which performs independent of operator speed. The spring-loaded activating mechanism ensures quick loadbreak or loadmake operations in less than one cycle. Incorporated into the switch mechanism are internal stops that restrict the handle orientation to only two positions: “OPEN” and “CLOSED” (see Figure 16). The switch should be hotstick-operated and will require 15 ft-lbs. minimum input torque to operate. Refer to Catalog Section CA800019EN Two-Position Sidewall (Horizontal) and Cover (Vertical) Mounted Loadbreak Switches for two-position loadbreak switch ratings. External visible loadbreak switch The Eaton’s Cooper Power series external visible loadbreak switch is a great way to verify isolation of internal transformer circuitry. Having visual confirmation that the secondary bushings are de-energized saves both time and money, while providing an added safety feature. It is strongly recommended that if breaking load with this switch, the viewing window be fully covered and locked into place. Viewing this switch during operation under load could be dangerous to the human eye. The external visible loadbreak switch is always shipped with a padlockable cover box. It is also important to remember that even after breaking load, the incoming high voltage cables are still live and dangerous. Figure 16. Two-position loadbreak switch handle and indicator plate. WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. • Do not operate loadbreak equipment if a fault condition is suspected. Doing so can cause an explosion or fire. • Use a hotstick to operate transformer loadbreak equipment. • After operating transformer loadbreak equipment, check that voltages at transformer terminals are the expected values. Checking voltages verifies that loadbreak equipment operated properly and that electrical circuit conditions are as expected. • Before servicing transformer secondary connected equipment, verify that all transformer secondary terminals have zero voltage and ground the transformer secondary terminals following industry accepted safe grounding practices. Grounding secondary terminals protects against situations such as a standby generator energizing transformer from the secondary circuit. • Before servicing transformer, ALWAYS de-energize the transformer from a remote upstream source and then proceed to ground all primary and secondary Sectionalizing loadbreak switch Eaton’s Cooper Power series sectionalizing loadbreak switch rotates 360° in either direction for alternate source selection. An externally-installed index plate prevents rotation to positions other than the one desired. The switch cannot be switched more than one position without resetting the index plate. A spring-loaded activating mechanism ensures quick loadbreak action and positive contact engagement through all positions. Switching can be accomplished in less than one cycle, and should be performed with a hotstick. To follow are operation examples for the two most common sectionalizing switch configurations. The following is a V-blade switch operation example (see Figure 17): If “A” is the feeder and it is desired to switch to “B” feeder, then the V-blade switch can be rotated as follows: 1. Set index stop plate between “line A only” and “Open”. 2. Rotate switch handle counterclockwise to “Open”. Transformer and loop conductor are now “Open”. 3. Move index plate between “Open” and “line B only”. 4. Rotate switch handle counterclockwise to “line B only”. Transformer is now energized for “B” feeder. The following is a T-blade switch operation example (see Figure 18): If “A” is the feeder and it is desired to switch to “B” feeder, the T-blade switch can be rotated as follows: 1. Set index stop plate between “line A only” and “loop thru transformer open”. 2. Rotate switch handle counterclockwise to “loop thru transformer open”. The transformer is now “OPEN” and the loop conductor is electrically connected. 3. Move index plate between “loop thru transformer open”” and “line b only”. 4. Rotate switch handle counterclockwise to “line b only”. The transformer is now energized for “B” feeder. For switch ratings and additional switch configurations refer to Catalog Section CA800005EN, Four-Position Sectionalizing Loadbreak Switches. Tap-changer Transformers equipped with a tap-changer can be changed from one operating voltage to another. The transformer must be de-energized and grounded before the tap-changer is operated. Operating voltages accessible through use of the tap-changer are indicated on the transformer nameplate. On most three-phase pad-mounted transformers equipped with tap-changers, the tap-changer operating handle is located on the faceplate in the high-voltage terminal compartment. The standard style of tap-changer will have a hotstick- operable handle. There are two styles of tap-changer with this type of handle, each requiring a slightly different method for changing tap settings. Figure 17. V-blade four-position sectionalizing switch handle and index plate. Figure 18. T-blade four-position sectionalizing switch handle and index plate. WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. De-energize transformer The tap-changer shown in Figure 19 can be switched to a new tap position as follows: 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals before operating the tap switch. 2. Back out lock screw to clear index plate. 3. Rotate handle to desired position. 4. Secure handle in its new position by tightening lock screw through index plate until it bottoms. 5. Padlocking may be accomplished through hole provided. The tap-changer shown in Figure 20 can be switched to a new tap position as follows: 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals before operating the tap switch. 2. Back out lock screw to clear index plate. 3. Pull handle out to clear index plate. 4. Rotate handle to desired position and allow pointer to drop into slot of index plate. 5. Secure handle in its new position by tightening lock screw through index plate until it bottoms. 6. Padlocking may be accomplished through hole provided. On some transformers, tap-changers have a lever handle (see Figure 21). A lock screw secures the handle at a particular setting. Such tap-changers can be switched to a new position as follows; 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals before operating the tap switch. 2. Back out lock screw to clear index plate. 3. Rotate handle to desired position. 4. Secure handle in its new position by tightening lock screw through index plate until it bottoms. Figure 19. Hotstick-operable tap-changer (Style I). Figure 20. Hotstick-operable tap-changer (Style II). Figure 21. Lever handle tap-changer. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 13 Page 33 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Dual-voltage and delta-wye switch Transformers equipped for dual-voltage or delta-wye (reconnectable winding) operations usually have an externally-operable switch mounted on the faceplate in the high-voltage terminal compartment. Units combining dual- voltage and delta-wye may have two separate switches. The transformer must be de-energized and grounded before dual-voltage or delta-wye switches are operated. Attempting to change dual-voltage or delta-wye switches on an energized transformer may result in damage to the equipment and severe personal injury. Dual-voltage windings are either connected in series (for the higher voltage) or in parallel (for the lower voltage). Dual- voltage and delta-wye switches have two positions. Switch positions are identified on the transformer nameplate and marked by corresponding numerals on the switch mounting plate. When dual-voltage or delta-wye switches are set to connect transformer windings in parallel, tap-changers must be in the position shown on the transformer nameplate. Tap-changers cannot be used to adjust voltage when transformer windings are connected in parallel. Improper tap-changer settings will cause circulating currents in the windings, which will damage the windings and cause failure of the transformer. To change dual winding switch settings: The standard type of dual-voltage or delta-wye switch will have a hotstick-operable handle (see Figure 22). This type of dual-voltage or delta-wye switch can be switched to a new position as follows: 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals before operating dual-voltage or delta- wye switch. 2. Back out lock screw to clear index plate. 3. Pull handle out to clear index plate and rotate handle 90°. Drop handle into new position. 4. Secure handle in its new position by tightening lock screw through index plate until it bottoms. 5. Padlocking may be accomplished through hole provided. On some transformers, dual-voltage or delta-wye switches have a lever handle (see Figure 23). This type of dual-voltage or delta-wye switch can be switched to a new position as follows: 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals before operating dual-voltage or delta- wye switch. 2. Back out lock screw to clear index plate. 3. Rotate handle 90° to new position. 4. Secure handle in its new position by tightening lock screw through index plate until it bottoms. Figure 22. Dual-voltage/delta-wye switch (hotstick- operable). Figure 23. Dual-voltage/delta-wye switch (lever handle). WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. De-energize transformer from a remote upstream source before operating non- Vacuum fault interrupter (VFI) Eaton’s Cooper Power series VFI transformers utilize vacuum interrupters to provide fault current interruption and load make/break switching capabilities. The VFI transformer uses the same technology used in Eaton’s Cooper Power series VFI pad-mounted switchgear. VFI transformers can be specified for either transformer protection or loop protection. A VFI transformer with transformer protection protects the transformer and provides proper coordination with upstream protective devices. A VFI transformer with loop protection protects the loop or downstream section of a feeder. Consequently, when a fault occurs downstream, the VFI breaker trips and isolates the fault, leaving the transformer load uninterrupted. The VFI interrupter mechanism in a VFI transformer has a hotstick-operable handle located on the faceplate of the transformer, with the operating mechanisms configured for ganged three-phase operation (see Figure 24). The VFI interrupter mechanism is opened by pulling the operation handle down to the open position. The VFI interrupter mechanism is closed by briskly pushing the handle up, into the closed position. If the VFI interrupter mechanism has tripped as the result of a fault or overload condition, the mechanism must be reset before it can be closed. To reset the mechanism, firmly pull the operation handle down toward the ground until the latch resets. After the latch has been successfully re-set, the VFI interrupter mechanism can be closed normally. Figure 24. VFI operating handle. IMPORTANT For 75 °C AWR transformers, applications with maximum ambient temperatures exceeding 30 °C or loading in excess of nameplate rating, contact your Eaton representative. WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. • Do not operate loadbreak equipment if a fault condition is suspected. Doing so can cause an explosion or fire. • Use a hotstick to operate transformer loadbreak equipment. • After operating transformer loadbreak equipment, check that voltages at transformer terminals are the expected values. Checking voltages verifies that loadbreak equipment operated properly and that electrical circuit conditions are as expected. • Before servicing transformer secondary connected equipment, verify that all transformer secondary terminals have zero voltage and ground the transformer secondary terminals following industry accepted safe grounding practices. Grounding secondary terminals protects against situations such as a standby generator energizing transformer from the secondary circuit. • Before servicing transformer, ALWAYS de-energize the transformer from a remote upstream source and then proceed to ground all primary and secondary transformer terminals following industry accepted safe grounding practices. Grounding secondary Current-sensing transformers (CTs) located inside the VFI transformer provide line current information to the electronic control. When line current exceeds the minimum trip setting, the control initiates a signal which causes the VFI interrupter mechanism to trip and then interrupt the circuit. All three phases will open when the VFI interrupter mechanism is tripped, regardless of whether the trip was single-phase or three-phase initiated. Refer to Service Information S285-75-1, Tri-Phase, TPG, and TPG with SCADA Electronic Control Installation and Operation Instructions for electronic control operation instructions. Standard electrical ratings for Eaton VFI transformers are as follows: Continuous Current (max) .....................600 A Interrupting Current (sym./asym.)...........12 kA/20 kA Momentary Current 10 cycles (asym.) ............20 kA 1-Second Withstand Current (sym.). .............12 kA Making Current (sym.) ........................12 kA For further information on Eaton VFI transformers including additional ratings, contact your Eaton representative. Air switches (Arc-Strangler®) WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. • Do not operate loadbreak equipment if a fault condition is suspected. Doing so can cause an explosion or fire. • Use a hotstick to operate transformer loadbreak equipment. • After operating transformer loadbreak equipment, check that voltages at transformer terminals are the expected values. Checking voltages verifies that loadbreak equipment operated properly and that electrical circuit conditions are as expected. • Before servicing transformer secondary connected equipment, verify that all transformer secondary terminals have zero voltage and ground the transformer secondary terminals following industry accepted safe grounding practices. Grounding secondary terminals protects against situations such as a standby generator energizing transformer from the secondary circuit. • Before servicing transformer, ALWAYS de-energize the transformer from a remote upstream source and then proceed to ground all primary and secondary transformer terminals following industry accepted safe grounding practices. Grounding secondary terminals protects against situations such as a standby generator energizing transformer from the secondary circuit. • Follow industry accepted safety practices. Utilize protective clothing and equipment when working with loadbreak equipment. WARNING Three-phase pad-mounted transformers use conventional transformer oil, R-Temp™ fluid, or Envirotemp™ FR3™ fluid for an insulating liquid. When the insulating liquid temperature is less than -20 °C (-4 °F) for conventional transformer oil, less than 0 °C Arc-Strangler loadbreaking device with NX® fusing NX® full-range current-limiting fuses up to 15.5 kV can be ordered with an integral Arc-Strangler® loadbreaking device. These in-air devices are mounted on the faceplate of the transformer. The Arc-Strangler device has the same operating characteristics as the basic NX clip-style fuse, along with loadbreaking capabilities. The Arc-Strangler loadbreaking device is a spring-loaded sliding sleeve that extinguishes the arc drawn between the mounting contacts and the fuse conductor when the fuse is opened while load current is flowing. All magnitudes of current through the continuous current rating of the fuse can be interrupted positively and safely under proper conditions. A pull-ring at the top of the fuse assembly (for hotstick operation) and a hinge at the bottom complete the loadbreak device. Arc-Strangler switchblades Switchblades with integral Arc-Strangler loadbreaking devices are available for use in NX type fuse mountings. Arc-Strangler switchblades are designed to break load current only (up to 200 A) and do not incorporate a fuse of any type for overload or fault interruption. Surge arresters Surge arresters are used in three-phase pad-mounted transformers to protect underground distribution equipment and cable from overvoltage surges. During steady state conditions, line-to-ground voltage is applied continuously across the arrester terminals. When surges occur, the arrester immediately limits the overvoltage to the required protective level by conducting the surge current to ground. Upon passage of the surge, the arrester returns to its initial state, conducting minimal leakage current. Surge arresters should be installed only on systems where the power frequency voltage at the arrester does not exceed published maximum continuous operating voltage (MCOV) values. The transformer should not be tested (impulse or applied potential) with the arrester connected. If connected during impulse tests, the arrester will clamp the discharge voltage applied by the test equipment. If the arrester is connected to the transformer during an applied potential test, there is a possibility that the arrester will be damaged. Disconnect surge arresters before tests are performed on the transformer. Arresters should be reconnected immediately after tests are completed. Under-oil MOV arrester Eaton’s Cooper Power series heavy-duty distribution-class under-oil MOV arrester is designed to be mounted inside the transformer tank (see Figure 25). Internal, under-oil mounting of the arrester prevents shortened arrester life due to surface contamination, wildlife damage, vandalism, or moisture ingress. Under-oil arresters are designed to operate when submerged in oil. It is recommended that the average oil temperature not exceed 90 °C and that the maximum oil temperature not exceed 125 °C. Figure 25. Heavy-duty distribution-class under-oil MOV arrester. WARNING Hazardous voltage. Can cause severe injury, death, or Under-oil arrester disconnection during test (with arrester disconnect switch) Eaton’s Cooper Power series arrester disconnector provides a means of disconnecting and reconnecting an under-oil arrester ground for transformer testing. Separate disconnectors are used for each arrester in the transformer, and are located on the transformer faceplate. The arrester disconnector is operated as follows: Operating from closed to open position (see Figure 26): 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals. 2. Unscrew handle from shaft. 3. Re-attach small diameter end of handle to shaft. 4. Push handle and shaft toward transformer until shaft flange (adjacent to handle) is flush to sealing gland. 5. Transformer is now ready for Impulse or Applied Potential testing. Operating from open to closed position: 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals. 2. Pull handle and shaft away from transformer completely. 3. Unscrew handle and re-attach with large diameter end toward the transformer. To assure good ground contact, the handle should be re-tightened by rotating handle 3/4 to 1 turn after handle has come in contact with seal gland. Under-oil arrester disconnection during test (with- out arrester disconnect switch) To disconnect arresters without a disconnect switch: 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals. 2. Remove tank cover following procedures in Tank Cover Removal and Installation section of this manual. 3. Locate arrester ground lead pad (see Figure 27) attached to tank wall. 4. Disconnect arrester ground leads from ground lead pad and separate leads ends a minimum of 5” from each other and from any part of the transformer. 5. Transformer is now ready for impulse or applied potential testing. To reconnect: 1. Reconnect arrester ground leads to ground lead pad. 2. Re-install tank cover as outlined in Tank Cover Removal and Installation section of this manual. CAUTION Before opening the transformer tank for internal maintenance, read the Insulating Liquid Maintenance section in this manual. This section explains safety precautions that should be taken and gives instructions on how to prevent insulating liquid contamination. Figure 26. Arrester disconnector operation. Figure 27. Under-oil arrester jumper ground lead pad with ground leads. 18 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 38 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 External arrester External surge arresters ordered with the transformer must be installed and connected in the field before the transformer is put into service. Arrester and tank ground connections must be completed before the transformer is connected to the high-voltage or low-voltage lines. Proper connection places the arrester in a direct shunt relationship to the transformer insulation. Maintenance Exterior maintenance On an annual or more frequent interval, inspect all exposed surfaces for evidence of tampering, battered metal, gouges, etc. Dents or deformities should be repaired at once. Scratched or weathered paint or protective coatings should be touched up promptly. Keep the area around the transformer clean. Do not store tools, materials or equipment on or against the transformer. Cabinet interior maintenance Periodically inspect the terminal compartment interior and all operating equipment. Check all gauges and controls for proper operation. Repair or replace damaged or defective equipment. Inspect drain cocks, plugs, fuse mountings, and switches. Look for evidence of insulating liquid seepage around tank- wall gaskets, seals, etc. Repair as required. Replacement of gaskets or seals in the tank wall may require that the tank be opened and the insulating liquid lowered to the appropriate level. For instruction on opening the tank and for draining and replacing the insulating liquid, refer to the Insulating Liquid Maintenance section in this manual. Tank internal maintenance (For Envirotran® Transformers see the Envirotran Transformers section of this manual before continuing) Service to bushings or equipment inside the transformer tank will require that the tank be opened and the insulating liquid lowered to the appropriate level. Before opening the transformer tank, read the Insulating Liquid Maintenance section in this manual. The Liquid Maintenance section explains safety precautions that should be taken and gives instructions on how to prevent insulating liquid contamination. Precautions must be taken to prevent dirt or moisture from entering the opened transformer tank. Contamination of the insulating liquid will prevent the transformer from operating properly and may cause serious damage to the transformer. Three-phase pad-mounted transformers may have either bolt-on or weld-on main tank covers. Bolt-on covers can be removed to access the tank interior. Access to the interior of a transformer with a weld-on tank cover is typically through a manhole/handhole. To gain additional internal access to tanks with weld-on tank covers, the tank cover must be cut open. Tank cover removal and installation (For Envirotran Transformers see the Envirotran Transformers section of this manual before continuing) WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. De-energize transformer from Transformers that have been system-connected should be de-energized, grounded, and disconnected before being opened for inspection. If the tank seal is broken, it is recommended that a leak test be performed to verify that the tank is properly sealed. To leak test, remove the pressure relief device and pressurize the headspace. The test pressure should not exceed 7 psig. The established pressure should be maintained for at least four hours to insure that all the seals are proper. Bolt-On tank cover removal Transformer tanks are factory-sealed to prevent ingress of ambient air and moisture. Do not open under any precipitation conditions. 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals before removing cover. 2. Thoroughly clean tank cover to help prevent contami- nation of insulating liquid when removing the cover. Remove all dirt, grease, and moisture. 3. From within the cabinet, remove the hardware (3/8” nuts using a 9/16” socket) which attaches the cover nutguard to the faceplate. 4. Relieve internal tank pressure by operating the pressure relief valve. Remove the hardware (3/8” nuts using a 9/16” socket) which attaches the cover to the tank. 5. Gently pry the cover upward. Do not allow the cover gasket to come in contact with the transformer insulat- ing liquid. Allowing the gasket to contact the liquid will make it slippery and difficult to hold in position during cover installation. Lift cover straight up to prevent dam- age to cover, bolts, and tank gasket. 6. Note the location and orientation (up/down) of each gasket section as they are removed from the tank flange so that they can be reinstalled properly. Bolt-On tank cover installation 1. Return the gasket sections to their original positions and orientation. 2. Re-install the cover, using 25 ft-lbs. torque to tighten the cover hardware. After installing all the nuts, re- torque each nut to ensure proper torque is achieved. 3. Remove the pressure relief valve and pressurize the headspace through the pressure relief valve coupling to ensure that there are no leaks. Test pressure should not exceed 7 psig. Established pressure should be main- tained for at least four hours to insure that all seals are proper. 4. Re-install the nutguard using 25 ft-lbs. torque to tighten nutguard access hardware. 5. Re-install pressure relief valve. Bolt-On manhole/handhole cover removal Transformer tanks are factory-sealed to prevent ingress of ambient air and moisture. Do not open under any precipitation conditions. 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals before removing cover. 2. From within cabinet, remove hardware (3/8” nuts using a 9/16” socket) attaching manhole/handhole access cover to cabinet. 3. Remove manhole/handhole access cover. Weld-on tank cover removal Transformer tanks are factory-sealed to prevent ingress of ambient air and moisture. Do not open under any precipitation conditions. Explosive gases can develop inside a transformer tank headspace during the life of the transformer. It is strongly recommended that weld-on cover removal be done only in a controlled repair facility by experienced maintenance personnel. To prevent explosions, the following procedures must be followed during weld-on cover removal: 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals before removing cover. 2. Relieve internal tank pressure by operating pressure relief valve. 3. Remove manhole/handhole cover as outlined in the Tank Cover Removal and Installation section of this manual. 4. Drain insulating liquid to the top of core clamp as outlined in the Insulating Liquid Maintenance section of this manual. 5. Allow transformer to sit with manhole/handhole removed for a minimum of 24 hours to allow explosive gases to escape. 6. Place a rubberized blanket on top of core clamp and completely cover core/coil assembly to protect core/coil assembly from weld spatter contamination during cover cutting. 7. Remove pressure relief valve and attach a nitrogen source in its place. 8. Fill headspace with nitrogen with manhole/ handhole cover still removed. Nitrogen gas will help prevent a volatile gas explosion while tank cover is being cut off. 9. While continuing to keep nitrogen flowing into the headspace, use carbon air arc machinery or a hard- wheel grinder to cut cover weld. 10. Thoroughly clean tank cover to help prevent contamination of insulating liquid when removing cover. Remove all dirt, grease, and moisture. 11. Remove tank cover from tank. Weld-on tank cover installation 1. Grind smooth and then clean cover, removing all weld spatter accumulated during cover removal. 2. It is recommended that the tank weld rope gasket be replaced around the tank lip prior to re-installing cover. The tank weld rope gasket helps prevent weld spatter from entering the tank during cover weld. The rubberized blanket installed during cover removal should still be covering the core/coil assembly. 3. Re-position cover on tank. 4. Fill headspace with nitrogen through pressure relief valve coupling, with manhole/handhole still removed. 5. Continue to keep nitrogen source flowing into headspace, and weld cover fully around the tank lip. 6. Remove rubberized blanket that was installed during cover removal. 7. Refill insulating liquid as outlined in Insulating Liquid Maintenance section of this manual. 8. Re-install manhole/handhole cover as outlined in Tank Cover Removal and Installation section of this man- Bushing removal and replacement 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals before performing maintenance on bushings. 2. Open tank by removing tank cover or manhole/ handhole cover as outlined in Tank Cover Removal and Installation section of this manual. 3. Lower insulating liquid level as outlined in Insulating Liquid Maintenance section of this manual. Lower liq- uid level to completely expose the bushing. 4. Disconnect all internal and external cable and leads. Note position of all nuts, flat washers, spring washers, etc., so they can be re-installed in same locations. 5. Remove all bushing clamp hardware, noting position of all nuts, flat washers, spring washers, etc., so they can be re-installed in same locations. 6. Remove external bushing clamp, bushing, and gasket. 7. Install a new bushing and gasket. Center bushing and gasket to obtain an effective seal. Install exterior bushing clamp and clamp hardware. Tighten clamp nuts per torque specified in Table 1. 8. Re-connect all external and internal cables and leads. Replace all nuts, flat washers, spring washers, etc., in their original position. Tighten all connections per torque specified in Table 1. 9. Restore insulating liquid to appropriate level as outlined in Insulating Liquid Maintenance section of this manual. Close, reseal, and leak test tank as outlined in the Tank Cover Removal and Installation section of this manual. Inspect bushing-to-tank seal for leaks or seepage. Cabinet removal and installation Cabinet removal 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals before performing maintenance on cabinet. 2. Place one 1/4 to 3/8 inch shim directly below faceplate on both sides of tank at points A and A’ (see Figure 28). 3. Place one 1 1/2 inch wedge under each side of cabinet at points B and B’ to relieve strain on the cabinet. 4. Note position and orientation of gasket that is between top of cabinet and tank so it can be re-installed in same fashion. 5. Disconnect HV-LV barrier from vertical bracket of face- plate. Bushing Clamps Clamp Type Hardware Tightening Torque Cast Aluminum Clamp 70-80 in-lbs. Molded Polymer Tri-Clamp 40-60 in-lbs. All other 3 & 4 hole Clamps 40-60 in-lbs. Table 1. Bushing Hardware Tightening Torque Bushings With Internal Spade Connections Bushing Hardware Hardware Tightening Torque 1/2” Steel (Grade 8) 50 ft-lbs. 3/8” Steel (Grade 8) 50 ft-lbs. Bushings With Internal Stud Connections Bushing Hardware Hardware Tightening Torque 3/8”-16 Brass Nuts 16 ft-lbs. 5/8”-11 Aluminum Nuts 60 ft-lbs. 6. Remove hardware attaching cabinet to faceplate on left and right sides of faceplate. Note position of all nuts, flat washers, spring washers, etc., so they can be re- installed in same locations. 7. Fully close HV and LV doors. 8. Slide cabinet assembly away from tank. Cabinet installation Reverse removal procedure to re-install cabinet. Re-attach cabinet using shims under front of tank and wedges under sides of cabinet, making sure cabinet gasket is inserted into cabinet back channel prior to attaching cabinet. Tighten cabinet hardware to 20 ft-lbs. torque. Insulating liquid maintenance Transformer tanks are factory-sealed to prevent ingress of ambient air and moisture. Do not open under any precipitation conditions. If it is necessary to drain and refill the transformer, special care should be taken to avoid the entrapment of gas bubbles in the system. Gas bubbles have lower dielectric integrity than the insulating liquid and will degrade the performance characteristics of the insulating system. Conventional oil-filled transformers Refer to IEEE Std C57.106™-2006 standard, “Guide For Acceptance and Maintenance of Insulating Oil in Equipment”, for additional guidelines when testing and handling conventional transformer oil. Periodic maintenance tests should be performed. R-Tran™ transformers Eaton’s Cooper Power series R-Tran™ transformers are filled with R-Temp fluid. R-Temp fluid is a non-toxic, readily biodegradable, less-flammable (high fire point), high molecular weight hydrocarbon dielectric fluid. Refer to IEEE Std C57.121™-1998 standard, “Guide for Acceptance and Maintenance of Less Flammable Hydrocarbon Fluids in Transformers.” Periodic maintenance tests should be performed on the same schedule as would be used for transformers of similar application filled with conventional transformer oil. Contact your Eaton representative for additional handling guidelines for R-Temp fluid. Mixtures of R-Temp fluid and conventional transformer oil R-Temp fluid is fully miscible with conventional transformer oil. There is no known detrimental performance impact when R-Temp fluid is mixed with conventional transformer oil. Conversely, except for some reduction in flash and fire points, the same is true for conventional transformer oil mixed with R-Temp fluid. Conventional transformer oil content of >3% in R-Temp fluid lowers the fire point below 300 °C. Measure the ASTM flash and fire points if the presence of conventional transformer oil is suspected. If flash or fire points fall below the minimum values required, retrofilling may be required. Envirotran® transformers Eaton’s Cooper Power series Envirotran® transformers are filled with Envirotemp™ FR3™ fluid. Envirotemp™ FR3™ fluid is a less-flammable (high fire point) dielectric fluid based on edible seed oils. Periodic maintenance should be performed on the same schedule as would be used for transformers of similar Bay-O-Net fuse replacement When replacing fuses in Flapper™ style Bay-O-Net fuse assembles, refer to Bay-O-Net Fuse Re-Fusing Instructions in this manual. Follow the same procedure as with conventional oil-filled transformers. Operation Eaton designs its transformers to operate at rated load with a temperature rise equal to or less than the temperature rise printed on the transformer’s nameplate. Operating transformers in excess of IEEE Std C57.91™-2011 standard will result in accelerated loss of insulation system life. The coil insulation has been carefully made with thermally- upgraded materials to ensure long life at rated loads. Severe and prolonged overloads of mineral oil-filled transformers will result in overheating and accelerated aging of the insulation, which may lead to premature failure. PEAK™ transformers have extended life and can be operated at higher temperatures. Refer to IEEE Std C57.154™-2012 standard for details. Mixtures of Envirotemp™ FR3™ fluid and conventional transformer oil Envirotemp™ FR3™ fluid is fully miscible with conventional transformer oil. There is no known detrimental performance impact when Envirotemp™ FR3™ fluid is mixed with conventional transformer oil. Conversely, except for some reduction in flash and fire points, the same is true for conventional transformer oil mixed with Envirotemp™ FR3™ fluid. Conventional transformer oil content of >7% in Envirotemp™ FR3™ fluid lowers the fire point below 300 °C. Measure the ASTM flash and fire points if the presence of conventional transformer oil is suspected. If flash or fire points fall below the minimum values required, retrofilling may be required. To maintain its exceptional environmental classification, mixing of Envirotemp™ FR3™ dielectric coolant with any other fluids should be avoided. Contact your Eaton representative for additional handling guidelines for Envirotemp™ FR3™ fluid. Sampling insulating liquid Before sampling the insulating liquid, verify that the tank is grounded. De-energize the transformer from a remote upstream source. Ground the bushings and terminals. Refer to ASTM D923 “Standard Practices for Sampling Electrical Insulating Liquids” for sampling techniques. A sample of the liquid should be taken when the liquid tem- perature is equal to or greater than the surrounding air to avoid condensation of moisture on the liquid. Containers used for sampling liquid should be clean and dry large mouth glass bottles. Make sure that the liquid being sampled is representative of the liquid in the unit. Sufficient liquid must first be drawn off to ensure that the sample will be from the bottom of the tank, and not the liquid stored in the sampling pipe Testing insulating liquid For the dielectric strength of the insulating liquids, follow the technique as specified by ASTM D877, “Standard Test Method for Dielectric Breakdown Voltage of Insulating Liquids Using Disk Electrodes”. If the dielectric strength of the liquid drops below 26 kV, it should be filtered until it tests at 26 kV or better. Filtering insulating liquid Restoring insulating liquid level If it is necessary to drain and refill the transformer, special care should be taken to avoid the entrapment of gas bubbles in the system. Sufficient time should be allowed between refilling and energization of the transformer to be sure that any gas bubbles created during the process have been dissipated. 1. Pump from bottom of temporary storage tank. Do not permit intake line to draw in air, since air bubbles will lower dielectric integrity of insulating system. 2. To prevent aeration at hose output, locate hose output below liquid surface 3. Pump slowly. If tank cover is not attached to tank, fill transformer to fill line marked on inside of transformer faceplate. If the tank cover is attached to tank, liquid level gauge may be read directly. On transformers that are not gauge-equipped, liquid level should be filled to bottom edge of liquid level plug hole (see Figure 3). Applicable standards 1. ASTM D92, “Standard Test Method for Flash and Fire Points by Cleveland Open Cup.” 2. ASTM D877, “Standard Test Method for Dielectric Breakdown Voltage of Insulating Liquids Using Disk Electrodes.” 3. ASTM D923, “Standard Practices for Sampling Electrical Insulating Liquids.” 4. IEEE Std C57.106™-2002 standard, “Guide For Acceptance and Maintenance of Insulating Oil in Equipment.” 5. IEEE Std C57.121™-1998 standard, “Guide for Acceptance and Maintenance of Less Flammable Hydrocarbon Fluids in Transformers.” Spare parts and service We suggest that one spare set of gaskets for manhole/ handhole and any gasket-type bushings be kept on hand. Other renewal parts may be ordered through your Eaton representative. When ordering parts, describe to your Eaton representative the maintenance being performed or the problem experienced. Also, tell the Eaton representative the complete transformer catalog number and serial number listed on the transformer nameplate. CAUTION It may be necessary to add extra liquid to the storage container from a reserve supply to replace the small quantity lost in the pump and lines and to prevent aeration of replacement liquid. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 25 Page 45 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Preventative maintenance instructions If any issues are found regarding the below, contact PS-WarrantyServices@ Eaton.com for assistance on transformers under warranty. Additionally, these reports must be available upon request to maintain warranty period. Transformer Exterior Maintenance Items to Inspect Points to be Checked Remedial Action Frequency Exterior Surfaces Inspect for evidence of tampering, battered metal, gouges, etc. Check for any damage that would allow the entrance of wires or other metallic devices. Any such damage should be repaired immediately. Annual Paint or Protective Coatings Inspect for scratches or weathering. Any such damage should be touched up immediately. Annual Tank Leaks Check tank exterior for signs of a leak. Any such leaks should be repaired immediately. Annual General Location Check the area around the transformer for stored tools, materials, equipment or debris. Anything on or against the transformer should be removed. Annual General Location Walk completely around unit and listen for abnormal noises; should be a steady hum without intermittent rattling Any such abnormal noises should be reported and investigated. Annual Pad Verify that pad has not tilted resulting in a transformer that is more than 5° from horizontal. If pad support is compromised or out of level greater than 5°, repair it immediately. Annual Nameplates Abnormal or unexpected fading of nameplates or decals. Contact your Eaton representative for replacement nameplates and decals as necessary. Annual Unusual Odors Smells of fluid or burning. This could be indicative of an unseen leak under the base. Also, inspect the concrete around the perimeter of the transformer base for oil spotting. Any such abnormal odors should be reported and investigated. Annual Cabinet Interior Maintenance Items to Inspect Points to be checked Remedial Action Frequency Gauges and Controls Check for proper operation. Repair or replace damaged or defective equipment. Annual Equipment Leaks Inspect drain cocks, plugs, fuse mountings, and switches. Look for evidence of insulating liquid seepage around tank-wall gaskets, seals, etc. Repair as required. Replacement of gaskets or seals in the tank wall may require that the tank be opened and the insulating liquid lowered to the appropriate level. For instruction on opening the tank and for draining and replacing the insulating liquid, refer to the Insulating Liquid Maintenance section. Items to Inspect Points to be checked Remedial Action Frequency Dielectric Fluid Level Check dielectric fluid level gauge. Note that the fluid level gauge has a notation as to the expected level when the unit has an average internal fluid temperature of 25 °C. A reading above this zone is normal when at full operating temperature and does not indicate that the transformer is operating at a temperature higher than the nameplate rating. If the dielectric fluid level is below the nominal level, check transformer for signs of a leak. If a leak is observed, repair immediately. If no leak is observed, add oil to bring level to nominal operating level. Annual Fluid Temperature Check liquid temperature gauge for elevated temperature. Reset the drag hand if one exists. Compare temperature to that of similar units. Note that the maximum top fluid temperature as noted by the draghand is a function of the maximum loading on the hottest day. A rule of thumb for a typical maximum reading would be nameplate rated temperature rise minus 10 °C plus the maximum ambient peak experienced in the area. Example: 65 °C - 10 °C + 40 °C = 95 °C. Similar units should be within 3 °C of each other at the same location. If temperature is elevated compared to other similar transformers, have unit serviced immediately to determine source of elevation. Annual Fusing If bayonet fuses have been extracted, fluid might be present from that activity and may not be indicative of a leak. Annual Cable Connections If there are signs of overheating, check for loose connections or discolored spades (paddles). The tin plating will achieve a rainbow coloring if a particular terminal is experiencing an over temperature condition. Tighten any loose connections immediately. Any damage or discoloration that is observed should be addressed immediately by a qualified technician. Annual Bushings Check condition of the HV and LV bushings. Observe for any indication of dirt, breakage, general damage, heat damage or flashover. Note that excess dielectric grease from the separable dead front connectors can liquefy from the heat and appear like an internal fluid leak. If the bushings are dirty, clean them immediately. Any damage that is observed should be addressed immediately by a qualified technician. Annual Cubicle Padlock Check that all cubicles are locked. Replace any missing locks immediately. Annual LV Bushing Cantilever Check for excessive cable weight or stiff cable conductors putting upward or downward pressure on the bushings due to pad settling. Immediately adjust cable/conductor position to Eaton 1000 Eaton Boulevard Cleveland, OH 44122 United States Eaton.com Eaton’s Cooper Power Systems Division 2300 Badger Drive Waukesha, WI 53188 United States Eaton.com/cooperpowerseries © 2015 Eaton All Rights Reserved Printed in USA Publication No. MN202001EN August 2015 For Eaton's Cooper Power series three- phase pad-mounted transformer product information call 1-877-277-4636 or visit: www.eaton.com/cooperpowerseries. ! SAFETY FOR LIFE Eaton is a registered trademark. All trademarks are property of their respective owners. Page 48 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 November 2, 2017 Attention: Mr. Richard Grill Phone: 970-484-4377 , e-mail: 26TUrgrill@cedfortcollins.comU26T Subject: Pad Mounted Transformer Site Acceptance Testing Eaton Negotiation Number DNK4171102-00AL Dear Mr. Grill : Thank you for considering Eaton’s Electrical Engineering Services & Systems (E-ESS) for your electrical solutions requirements. This proposal outlines our proposed scope of work at the jobsite. 1. PROJECT SUMMARY • Acceptance testing of the following Equipment 2. EQUIPMENT BILL OF MATERIAL • Qty (1) 1000KVA Pad-Mounted Liquid filled transformer 3. SCOPE OF WORK Eaton Corporation will provide the necessary field service personnel, tools, materials and approved test equipment to perform the scope of work as described herein. Qty (1) 1000KVA PDMT XFMR - 13200GY/7620 -277/480V • Acceptance testing will be performed per the Acceptance Testing Standard Guidelines • Onsite assistance for performing final adjustments and minor alterations • Perform a turns-ratio test and retest on tap as left and record • Collect an fluid sample to be sent to a test lab for analysis • Complete a benchmark Dissolved Gas Analysis (DGA) for future maintenance records. A comprehensive engineering report including findings, test data, and recommendations will be furnished after completion of work. 4. COMPLETION Upon completion of the project, Eaton will: • Furnish a comprehensive engineering report including findings, test data, and recommendations 5. PRICING Total NET $1,750.00 Price for the above scope of work is based on performing site work on a weekday-day turn. If the work cannot be performed during regular working hours (6am-5pm) or must be performed on weekends or holidays, please contact us to adjust the price accordingly. Page 49 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 6. DELIVERY The scheduling of work will be mutually agreed upon between the customer and Eaton’s Electrical Engineering Services & Systems. Please allow two weeks for scheduling purposes. 7. ORDER ENTRY Eaton Corporation 8022 Southpark Circle, Suite 300 Littleton, CO 80120 Attn: Nicole Shrader, Email: NicoleLShrader@Eaton.com Phone: (303) 738-2360 Fax (303) 762-0419 Remit to Address: Eaton Corporation P.O. Box 93531 Chicago, IL 60673-3531 8. QUALIFICATIONS / CLARIFICATIONS • All work to be completed at straight time, Monday through Friday except for scheduled outages as defined in our proposal. • Minor repairs and adjustments taking a minimal amount of time will be included in our base price. If additional time or material is required, it will be charged as an extra. • Any significant delays due to adverse weather will result in additional charges. • If straight time work is required to be performed on an overtime basis, Customer will be billed the difference between the straight time and overtime rate. • Stand-by power needs, if deemed necessary, are not included. • Applicable fees for outage related costs including stand-by and re-connect services are not included. • Eaton will correct minor deficiencies. Minor deficiencies are those that require no special tools, parts, etc. and take a minimal amount of time to perform. Repair labor beyond this, and all material, will be considered as extra. • Method of procedure (MOP) development or meeting time not outlined in the scope of work will be treated as an extra. • Replacement parts and additional labor required to perform any repairs necessary for proper operation of your equipment will be accomplished exclusively at your written direction and authorization. • Delays beyond the control of Eaton, extras and authorized additional work will be charged in accordance with the Eaton’s Electrical Engineering Services & Systems 2015 Price List PL02700001E. • Delay time: If Eaton arrives onsite to perform scheduled work and the work is cancelled, Eaton will charge for four (4) hours minimum per person, plus travel expenses if no replacement work can be scheduled. If sufficient notice (72 hours) is given to Eaton when canceling scheduled work, no additional charge will apply. • Third party billing will be subject to an additional 15% fee. 9. TESTING CLARIFICATIONS: Page 50 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 • If NETA testing is specified, and provided by Eaton, Eaton takes exception to NETA certification and membership or Nationally Recognized Testing Laboratory (NRTLs) requirements. Eaton is an independent service division of Eaton Corporation fully qualified to perform the required testing. An additional year of warranty shall be provided upon completion of electrical testing by Eaton to all Eaton provided equipment. • 1TEaton EESS is (NICET) certified 1T15TNational Institute for Certification in Engineering Technologies1T15T • Customer to provide settings and relay logic configuration files for protective devices. Note: Eaton can provide an adder for the required power system studies and input/output logic. • The isolation of cables for testing will be completed by opening the line and load devices only. No unbolting of cables for isolation has been included. 10. SAFETY TRAINING OF EATON FIELD PERSONNEL: • All Eaton field personnel received training to comply with OSHA CFR1910 Electrical Safety Standard, which sets minimum safety rules and practices for the design, operation, and maintenance of high-voltage systems (over 600 volts). Safety standards are in place to meet or exceed NFPA 70E requirements, and appropriate Personal Protective Equipment (PPE) have been issued. • The customer is responsible to ensure that any supporting plant personnel have also be fully trained in electrical safety and provided with the appropriate personnel protective equipment. 11. SAFETY ARC-FLASH PROVISIONAL STATEMENT: The customer supplied Arc-Flash study along with their labeled equipment to meet NFPA requirements will be used to determine the Personal Protective Equipment (PPE) required to perform the work required for this proposal. When a current study and labeling is not available, the time required to determine the proper PPE will be at the current rate per hour, unless included within the Eaton scope of work. Eaton will not perform work activities in situations where the proper level of PPE is not practical. At no time will work be performed when the arc-flash exposure levels are above 40 cal/cmP 2 P. 12. DIVISION OF RESPONSIBILITY Eaton Responsibilities: • Eaton will perform necessary adjustments, which are required to bring equipment to satisfactory operating condition, or review these with you prior to commencement of any additional work. • Eaton will obtain authorization in advance before performing any additional work. In these cases, Eaton will provide services on a time and material basis. Eaton will provide a listing of all applicable skills classifications that apply to the execution of this contract, and identify the hourly rates (both straight time and overtime) that will apply for the duration of the contract. Eaton will also indicate escalation if applicable and, and in addition, provide a definition of when overtime rates apply. • Eaton will provide you with a minimum notice of 72 hours of intent to service any equipment. • Eaton shall furnish test engineers, field technicians, support personnel, tools, equipment, materials, supplies and transportation as required. • Eaton will provide and install safety locks, as required, and in accordance with the facility safety guidelines. • Eaton will perform voltage test and install necessary circuit / equipment safety grounds to assure safe working conditions Page 51 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 • Upon completion of work: 1) Eaton will remove safety grounds installed by Eaton 2) Eaton will remove safety locks installed by Eaton. Customer Will Be Responsible For The Following: • Providing free access to equipment within their facility. • Ensuring that all equipment is available upon arrival of Eaton personnel, including removal from service to permit continuous progression of work. Delay time in making equipment available will be treated as an extra. • Identifying site contact for this project. • Providing electricians to remove equipment covers and re-install the same when required. • Coordinating all outages and perform all switching to de-energize and isolate equipment to be serviced. • Ensuring that all circuits to be de-energized have been clearly identified and that all plant personnel and downstream operations are aware of the required outage date, time and duration. This includes maintaining power to vital or necessary plant equipment and processes during the performance of this scope of work. • Providing a copy of the past maintenance records to Eaton personnel. • Providing manufacturers maintenance manuals upon arrival of Field Engineer/s. • Supplying a complete set of electrical plans, including the plant single-line diagram, specifications, and any pertinent change orders to Eaton before commencement of work. • Supply a suitable and stable source of power for operation of test and motorized equipment at each test site when normal power is removed or authorize Eaton to obtain a source of auxiliary power, Eaton shall specify requirements. Any non-standard generators rentals will result in a price adder to this proposal. • Providing a place to receive and unload replacement equipment, test equipment or other supplies. 13. TERMS AND CONDITIONS Any order arising out of this offer will be governed by the conditions contained in Eaton Selling Policy 25-000 dated November 1, 2008. Taxes, if applicable, not included. This offer is valid for 30 days unless otherwise extended, modified or withdrawn, in writing, by Eaton. Payments are due and payable net within thirty (30) days from the date of each invoice. Please reference negotiation number SL10170327-01AL on any purchase order issued in response to this proposal. It is a privilege to have this opportunity to be of service. If there are any further questions or needs, please contact me at 303-738-2382 or by email at TonyShortino@Eaton.com. Eaton’s Electrical Engineering Services & Systems looks forward to working with you on this project. Sincerely, Tony Shortino Tony Shortino Service Sales Engineer Page 52 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Eaton’s Electrical Engineering Services & Systems Uhttp://www.eaton.com/eessU 24-Hour Emergency Service: 1-800-498-2678 Attachments: Eaton Selling Policy 25-000 Page 53 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 The following describes the electrical scope of work for Interstates’ portion for the procurement of SSB 1204 and HVT 1204 project located at the DWRF facility in Fort Collins, CO. Proposal Documentation Our proposal is based on the following: 1. Carollo project NO. 10545B10 Technical Specifications Dated October, 2017 2. Drawing ESD-EDD-06 SSB1204 One-Line Diagram SSB 1204 1. SSB1204 a) Interstates will procure (1) 2000AMP NEMA 3R Switchboard per one-line and specifications. 2. Lead times a) Equipment lead times from factory: 12-14 weeks after approval. b) Approval Drawings: 6 weeks. 3. Submittals a) Interstates will provide submittal packages in accordance with Carollo specifications. HVT 1204 1. HVT-1204 a) Interstates will procure (1) 1000KVA 13.2KV-480/277V NEMA 3R transformer per one-line and specifications. 2. Lead times a) Equipment lead times from factory: 11-13 weeks after approval. b) Approval Drawings: 3-4 weeks. 3. Submittals a) Interstates will provide submittal packages in accordance with Carollo specifications. Pricing & Payment Terms Total all options $ 73,495 SSB 1204 Item Price Specification Reference SSB 1204 Base Price* $ 18,802 26_24_14 /26_28_01 Startup $ 5,289 1_75_17-3/1.04 Training $ 3,330 01_75_17-8/1.06.C Dedicated Truck $ 6,050 26_12_20-3/ 1.07.B.1.2.3 Total $ 33,471 *Includes Interstates’ General Conditions + 2year warranty HVT 1204 Item Price Specification Reference HVT 1204 Base Price* $ 29,031 26_12_20 Source Testing $ 1,925 01_75_17-6 /1.06 Two Year Warranty $ 818 26_05_00 Dedicated Truck $ 8,250 26_12_20-3/ 1.07.B.1.2.3 Total $ 40,024 *Includes Interstates’ General Conditions DWRF Dewatering SSB & HVT1204 Scope of Work Fort Collins, CO November Page 54 10, of 2017 166 Page 1 of 2 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Project Exclusions 1. Provision of temporary heat for switchboard during or after transit. (Spec section 26_24_14 1.07C) 2. Sales tax Clarifications 1. If any part of this project is considered exempt from taxes, we will require that the owner or general contractor file the required exemption certificates with Interstates. We would also request that you sign a letter holding us harmless for taxes or penalties charged to Interstates because of our reliance on these exemptions. A copy of this letter will be provided at your request. 2. There may be clarifications and/or modifications that we will need to discuss prior to finalizing the price and signing the contract. 3. Interstates believes that successful projects have balanced contracts where risk is managed by the party best equipped for that risk. Our price is based on a contract risk profile that includes: a. Indemnification that extends only to bodily injury and property damage to the extent we negligently caused the claim. b. Our bond and/or lien rights are preserved. c. A mutual waiver of consequential damages. 4. We anticipate no liquidated damages will be applied to our contract. 5. We assume that a maximum of 5% retainage will be withheld from our monthly progress billing. All materials, whether stored or installed, are billable. All invoices are due net, thirty (30) days. Accounts unpaid thirty (30) days after the invoice date are subject to a monthly service charge of 1.5% on the then unpaid balance (18.0% true annual rate). In the event any portion or all of an account remains unpaid 90 days after billing, the Client shall pay all costs of collection, including reasonable attorney’s fees. 6. Upon execution of this agreement, an initial payment of 5% of the total amount shall be made to Interstates. The amount of the initial payment shall be credited to your account at the final payment. 7. While Interstates strives to minimize project changes, extra work orders (EWO’s) can be caused by changes in scope, schedule, etc. If necessary, EWO’s will be submitted in writing. Written approval must be received from the client prior to starting the associated work. Closing Thank you again for the opportunity to offer this proposal. Please don’t hesitate to contact us if you have any questions or if there is anything else we can assist with. Sincerely, Interstates Construction Services, Inc. Daron Pursley Estimator (970) 221-1776 x7504 Daron.Pursley@Interstates.com DWRF Dewatering SSB & HVT1204 Scope of Work Fort Collins, CO November Page 55 10, of 2017 166 Page 2 of 2 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 56 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 57 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 58 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 59 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 01_11_00 SUMMARY OF WORK PART 1 GENERAL 1.01 SUMMARY A. Section includes: Detailed description of the Work for the Supply of a Transformer and Switchboard. B. Related sections: 1. Section 26_12_20 - Liquid Filled Pad Mounted Transformers. 2. Section 26_24_14 - Group-Mounted Circuit Breaker Switchboards. 1.02 THE WORK A. The Work consists of supply of the equipment as described in Sections 26_12_20, 26_24_14, and related sections, including submittals, equipment, start-up, and commissioning services, spare parts, and coordination with the Contractor during installation. Equipment will be installed outside existing Dewatering Facility. 1.03 LOCATION OF PROJECT A. The Work is located at the Drake Water Reclamation Facility, 3036 Environmental Drive, Fort Collins, CO 80525. 1.04 RESPONSIBLE PARTIES A. The following define the responsible parties associated with the Project: 1. Owner: City of Fort Collins. 2. Contractor: Hydro Construction. 3. Engineer: Carollo Engineers. 4. Supplier: Manufacturer and Supplier of Transformer and Switchboard Equipment. Also referred to as Manufacturer or Vendor. PART 2 PRODUCTS Not Used. PART 3 EXECUTION Not Used. END OF SECTION Page 60 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 61 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 01_33_00 SUBMITTAL PROCEDURES PART 1 GENERAL 1.01 SUMMARY A. Section includes: Requirements and procedures for submittals. B. Related sections: 1. Section 26_12_20 - Liquid Filled Pad Mounted Transformers. 2. Section 26_24_14 - Group-Mounted Circuit Breaker Switchboards. 3. Section 26_28_01 - Low Voltage Molded Case Circuit Breakers. 1.02 DEFINITIONS A. Certificates: Describe certificates that document affirmations by the Supplier or other entity that the work is in accordance with the Contract Documents. B. Extra stock materials: Describe extra stock materials to be provided for the Owner's use in facility operation and maintenance. C. Maintenance material submittals: Use this article to categorize maintenance materials submittals requiring no Engineer action other than confirmation of receipt under an explanatory heading. D. Manufacturer's instructions: Instructions, stipulations, directions, and recommendations issued in printed form by the manufacturer of a product addressing handling, installation, erection, and application of the product; manufacturer's instructions are not prepared especially for the Work. E. Product data: Product data usually consists of manufacturers' printed data sheets or catalog pages illustrating the products to be incorporated into the project. F. Samples: Samples are full-size actual products intended to illustrate the products to be incorporated into the project. Sample submittals are often necessary for such characteristics as colors, textures, and other appearance issues. G. Spare parts: Describe spare parts necessary for the Owner's use in facility operation and maintenance; identify the type and quantity here, but include the actual characteristics of the spare parts in Product as part of the specification of the product. H. Shop drawings: Shop drawings are prepared specifically for the project to illustrate details, dimensions, and other data necessary for satisfactory fabrication or construction that are not shown in the contract documents. Shop drawings could include graphic line-type drawings, single-line diagrams, or schedules and lists of products and their application. Page 62 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 I. Submittals: Submittals are samples, product data, shop drawings, and others that demonstrate how Supplier intends to conform with the Contract Documents. J. Tools: Tools are generally defined as items such as special wrenches, gauges, circuit setters, and other similar devices required for the proper operation or maintenance of a system that would not normally be in the Owner's tool kit. 1.03 GENERAL INSTRUCTIONS A. Provide submittals that are specified or reasonably required for construction, operation, and maintenance of the Work. B. Provide submittal information from only 1 manufacturer for a specified product. Submittals with multiple manufacturers for 1 product will be rejected without review. C. Where multiple submittals are required, provide a separate submittal for each specification section. 1. In order to expedite construction, the Supplier may make more than 1 submittal per specification section, but a single submittal may not cover more than 1 specification section. 2. The only exception to this requirement is when 1 specification section covers the requirements for a component of equipment specified in another section. D. For example, circuit breakers are a component of switchgear. The switchgear submittal must also contain data for the associated circuit breakers, even though they are covered in a different specification section. E. Edit all submittals so that the submittal specifically applies to only the equipment furnished. Neatly cross out all extraneous text, options, models, etc. that do not apply to the equipment being furnished, so that the information remaining is only applicable to the equipment being furnished. F. Prepare submittals in the English language. Do not include information in other languages. G. Present measurements in customary American units (feet, inches, pounds, etc.). H. Show dimensions, construction details, wiring diagrams, controls, manufacturers, catalog numbers, and all other pertinent details. I. Indicate project designated equipment tag numbers from P&IDs for submittal of devices, equipment, and assemblies. J. Submittals shall be provided in electronic media format: 1. General: Provide all information In PC-compatible format using Windows® operating system. 2. Text: Provide text documents and manufacturer’s literature using current version of Adobe® Acrobat® (i.e., PDF extension). 3. Graphics: Provide all graphic submittals (drawings, diagrams) utilizing current version of Adobe® Acrobat® (i.e., PDF extension). 4. Supplier using other software shall be required to provide conclusive evidence of 100 percent data transfer compatibility that is an equal to PDF format. Page 63 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 1.04 SUBMITTAL ORGANIZATION A. Fully indexed electronic submittal with a tabbed divider for every component. B. Sequentially number pages within the tabbed sections: 1. Submittals that are not fully indexed and tabbed with sequentially numbered pages, or are otherwise unacceptable, will be returned without review. C. Organize submittals in exactly the same order as the items are referenced, listed, and/or organized in the specification section. D. For submittals that cover multiple devices used in different areas under the same specification section, the submittal for the individual devices must list the area where the device is used. E. Consolidate electronic format submittals with multiples pages into a single file. 1.05 SUBMITTAL COVER SHEETS A. Submittal Transmittal Form is provided in Appendix A of this Section. 1. Contractor submittal transmittal form is acceptable providing that it includes information, statements, and certifications comparable to the Submittal Transmittal Form. 2. Submittal Number Field: Required submittal numbering format: Section number-sequential number-resubmittal number: a. Example: 03_20_00-002-1: 1) “03_20_00” indicates the affected specification is Section 03_20_00. 2) “002” indicates the second submittal under this Section. 3) “1” indicates the first resubmittal of the Submittal. b. Contractor may add a separate numbering scheme for Contractor’s internal use. However, all correspondence with Engineer must include the required submittal numbering. 3. “From” Field: Provide name and address of company responsible for preparation of submittal. 4. “General Contractor Reviewer” Field: Verify that the Contractor has reviewed the submittal by signature. B. Contractor sign and date submittals indicating review and approval: 1. Signature indicates Contractor certifies that they have satisfied submittal review responsibilities and constitutes Contractor's written approval of submittal. Contractor shall note that the submittal complies with the Specification Section. C. Attachments: 1. Specification section deviations: a. Provide a list of all numbered deviations, with reference to Specification Section and pertinent paragraph, with a clear explanation and reason for the deviation. 2. Drawings deviations: a. Provide a list of all numbered deviations, with reference to specific Drawing, with a clear explanation and reason for the deviation. b. Provide field dimensions and relationship to adjacent or critical features of the Work or materials. Page 64 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 D. Supplier: Prepare submittal information in sufficient detail to show compliance with specified requirements. 1. Determine and verify quantities, field dimensions, product dimensions, specified design and performance criteria, materials, catalog numbers, and similar data. 2. Coordinate submittal with other submittals and with the requirements of the Contract Documents. 3. Check, verify, and revise submittals as necessary to bring them into conformance with Contract Documents and actual field conditions. 1.06 SUBMITTAL CONTENT A. Shop drawings: 1. Details: a. Fabrication drawings: drawn to scale and dimensioned. b. Front, side, and, rear elevations, and top and bottom views, showing all dimensions. c. Locations of conduit entrances and access plates. d. Component layout and identification. e. Weight. f. Finish. g. Temperature limitations, as applicable. h. Nameplate information. B. Product information: 1. Product data: a. Details: 1) Supplier name and address. 2) Subcontractor name and address. b. Include: 1) Catalog cuts. 2) Bulletins. 3) Brochures. 4) Manufacturer’s Certificate of Compliance: signed by product manufacturer along with supporting reference data, affidavits, and tests, as appropriate. 5) Manufacturer’s printed recommendations for installation of equipment. 6) Quality photocopies of applicable pages from manufacturer’s documents. 2. Samples: a. Details: 1) Submit labeled samples. 2) Samples will not be returned. 3) Provide samples from manufacturer’s standard colors, materials, products, or equipment lines. a) Clearly label samples to indicate any that represent non-standard colors, materials, products, or equipment lines and that if selected, will require an increase in Contract Time or Contract Price. Page 65 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 3. Minor or incidental products and equipment schedules: a. Details: 1) Shop Drawings of minor or incidental fabricated products will not be required, unless requested. 2) Submit tabulated lists of minor or incidental products showing the names of the manufacturers and catalog numbers, with Product Data and Samples as required to determine acceptability. C. Design calculations: 1. Details: a. Defined in technical sections. b. Calculations must bear the original seal and signature of a Professional Engineer licensed in the state where the project is located and who provided responsible charge for the design. D. Qualifications statements: 1. Details: a. Defined in technical sections. b. Licensing documentation. c. Certification documentation. d. Education documentation. E. Quality assurance/control submittals: 1. Mill test reports: a. Details: 1) Submit certified copies of factory and mill test reports. 2) Do not incorporate Products in the Work which have not passed testing and inspection satisfactorily. 2. Test Reports, for tests required in accordance with technical specifications: a. Details: 1) Include the following information: a) A description of the test. b) List of equipment used. c) Name of the person conducting the test. d) Date and time the test was conducted. e) Ambient temperature and weather conditions. f) All raw data collected. g) Calculated results. h) Clear statement if the test passed or failed the requirements stated in Contract Documents. i) Signature of the person responsible for the test. 3. Factory Acceptance Test: a. Details: Include complete test procedure and all forms to be used during test. 4. Certificates: a. Details: Defined in technical sections. 5. Manufacturers’ field reports: a. Details: Manufacturer’s Certificate of installation and functionality compliance. Page 66 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 6. Field samples: a. Details: Defined in technical sections. 7. Test plans: a. Details: Defined in technical sections. 1.07 SUBMITTAL PROCEDURE A. Supplier: 1. Delivery: Deliver electronic submittals to Contractor, unless another mutually agreeable place is designated. 2. Timeliness: Schedule and make submissions in accordance with the requirements of the individual specification sections and in such a sequence as to cause no delay in Work. B. Engineer: Review submittal and provide response. 1. Review description: a. Engineer will be entitled to rely upon the accuracy or completeness of designs, calculations, or certifications made by licensed professionals accompanying a particular submittal whether or not a stamp or seal is required by Contract Documents or Laws and Regulations. b. Engineer's review of submittals shall not release Supplier from Supplier's responsibility for performance of requirements of Contract Documents. Neither shall Engineer's review release Supplier from fulfilling purpose of installation nor from Supplier's liability to replace defective work. c. Engineer's review of shop drawings, samples, or test procedures will be only for conformance with design concepts and for compliance with information given in Contract Documents. d. Engineer's review does not extend to: 1) Accuracy of dimensions, quantities, or performance of equipment and systems designed by Contractor. 2) Supplier's or Contractor's means, methods, techniques, sequences, or procedures except when specified, indicated on the Drawings, or required by Contract Documents. 3) Safety precautions or programs related to safety which shall remain the sole responsibility of the Contractor. 2. Review timeframe: a. Except as may be provided in technical specifications or under special circumstances, a submittal will be returned within ten (10) working days. b. When a submittal cannot be returned within the specified period, Engineer will, within a reasonable time after receipt of the submittal, give notice of the date by which that submittal will be returned. 3. Schedule delays: a. No adjustment of Contract Times or Contract Price will be allowed due to Engineer’s review of submittals, unless all of the following criteria are met: 1) Engineer has failed to review and return first submission within the agreed upon time frame. 2) Supplier demonstrates that delay in progress of Work is directly attributable to Engineer’s failure to return submittal within time indicated and accepted by Engineer. Page 67 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 4. Review responses: 1 copy of submittal will be returned to Contractor and Supplier with one of the following reviewer’s response. a. Approved: 1) No Exceptions: a) There are no notations or comments on the submittal and the Supplier may release the equipment for production. 2) Make Corrections Noted - See Comments: a) The Supplier may proceed with the work, however, all notations and comments must be incorporated into the final product. b) Resubmittal not required. 3) Make Corrections Noted - Confirm: a) The Supplier may proceed with the work, however, all notations and comments must be incorporated into the final product. b) Submit confirmation specifically addressing each notation or comment to the Engineer within 15 calendar days of the date of the Engineer’s transmittal requiring the confirmation. b. Not approved: 1) Correct and Resubmit: a) Supplier may not proceed with the work described in the submittal. b) Supplier assumes responsibility for proceeding without approval. c) Resubmittal of complete submittal package is required within 15 calendar days of the date of the Engineer’s submittal review response. 2) Rejected - See Remarks: a) Supplier may not proceed with the work described in the submittal. b) The submittal does not meet the intent of the Contract Documents. Resubmittal of complete submittal package is required with materials, equipment, methods, etc. that meet the requirements of the Contract Documents. c. Receipt Acknowledged: Filed for Record: 1) This is used in acknowledging receipt of informational submittals that address means and methods of construction such as schedules and work plans, conformance test reports, health and safety plans, etc. C. Supplier: Prepare resubmittal, if applicable. 1. Clearly identify each correction or change made. 2. Include a response in writing to each of the Engineer’s comments or questions for submittal packages that are resubmitted in the order that the comments or questions were presented throughout the submittal. a. Acceptable responses to Engineer’s comments are listed below: 1) “Incorporated” Engineer’s comment or change is accepted and appropriate changes are made. 2) “Response” Engineer’s comment not incorporated. Explain why comment is not accepted or requested change is not made. Explain how requirement will be satisfied in lieu of comment or change requested by Engineer. b. Reviews and resubmittals: 1) Supplier shall provide resubmittals which include responses to all submittal review comments separately and at a level of detail commensurate with each comment. Page 68 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 2) Supplier responses shall indicate how the supplier resolved the issue pertaining to each review comment. Responses such as “acknowledged” or “noted” are not acceptable. 3) Resubmittals which do not comply with this requirement may be rejected and returned without review. 4) Supplier shall be allowed no extensions of any kind to any part of their contract due to the rejection of non-compliant submittals. 5) Submittal review comments not addressed by the Supplier in resubmittals shall continue to apply whether restated or not in subsequent reviews until adequately addressed by the Supplier to the satisfaction of the reviewing and approving authority. c. Any resubmittal that does not contain responses to the Engineer’s previous comments shall be returned for Revision and Resubmittal. No further review by the Engineer will be performed until a response for previous comments has been received. 3. Resubmittal timeframe: a. Supplier shall provide resubmittal within 15 days. b. When a resubmittal cannot be returned within the specified period, Supplier shall notify Contractor in writing. 1.08 SUPPLIER’S PROFESSIONAL ENGINEER (P.E.) CERTIFICATION FORM A. Submit a completed Supplier’s P.E. Certification Form, provided in this Section, to comply with technical sections requirement for a professional engineer’s certification for design of the anchor bolts from an engineer licensed in the state the project is located. PART 2 PRODUCTS Not Used. PART 3 EXECUTION Not Used. END OF SECTION Page 69 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 APPENDIX A CONTRACTOR SUBMITTAL TRANSMITTAL FORM Page 70 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 DOCUMENT 01_33_00 CONTRACTOR SUBMITTAL TRANSMITTAL FORM Owner: Date: Contractor: Project No.: Project Name: Submittal Number: Submittal Title: To: From: Specification No. and Subject of Submittal / Equipment Supplier Spec ##: Subject: Authored By: Date Submitted: Submittal Response Check Either (A) or (B): (A) We have verified that the equipment or material contained in this submittal meets all the requirements specified in the project manual or shown on the contract drawings with no exceptions. (B) We have verified that the equipment or material contained in this submittal meets all the requirements specified in the project manual or shown on the contract drawings except for the following deviations (list deviations): Certification Statement: By this submittal, I hereby represent that I have determined and verified all field measurements, field construction criteria, materials, dimensions, catalog numbers and similar data, and I have checked and coordinated each item with other applicable approved shop drawings and all Contract requirements. General Contractor’s Reviewer’s Signature: Printed Name: In the event, Contractor believes the Submittal response does or will cause a change to the requirements of the Contract (i.e., schedule or budget impacts), Contractor shall immediately give notice to Owner. Firm: Signature: Date Returned: PM/CM Office Use Date Received GC to PM/CM: Date Received PM/CM to Reviewer: Date Received Reviewer to PM/CM: Date Sent PM/CM to GC: Page 71 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 APPENDIX B SUPPLIER’S P.E. CERTIFICATION FORM Page 72 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 DOCUMENT 01_33_00 SUPPLIER’S P.E. CERTIFICATION FORM Owner: Date: Contractor: Registration State: Project Name: Project No.: Responsibilities: Spec Section: Statement of Certification The undersigned hereby certifies that he/she is a professional engineer registered in the State of and that he/she has been employed by The undersigned further certifies that he/she has performed the said design in conformance with all applicable local, state, and federal codes, rules, and regulations; and, that his/her signature and P.E. stamp have been affixed to all calculation and drawings used in, and resulting from, the design. The undersigned hereby agrees to make all original design drawings and calculations available to: (Name of Owner, or Owner’s representative within 7 days of receiving a written request by the Owner.) Prof. Engineer Signature: Date: Printed Name: Company Name: Contractor’s Signature: Date: Printed Name: Page 73 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 01_41_00 REGULATORY REQUIREMENTS PART 1 GENERAL 1.01 SUMMARY A. Section includes: Regulatory authorities and codes. 1.02 AUTHORITIES HAVING JURISDICTION A. Fire Department: Poudre Fire Authority. 1.03 APPLICABLE CODES A. International Code Council (ICC): 1. Building code: a. International Building Code (IBC), 2012. 1) City of Fort Collins local amendments. 2. Electrical code: a. National Fire Protection Association (NFPA), NFPA 70: National Electrical Code (NEC), 2014. 3. Energy code: a. International Energy Conservation Code (IECC), 2012. 1) City of Fort Collins local amendments. 4. Fire code: a. International Fire Code (IFC), 2012. 5. Fuel gas code: a. International Fuel Gas Code (IFGC) – 2012. 1) City of Fort Collins local amendments. 6. Mechanical code: a. International Mechanical Code (IMC), 2012. 1) City of Fort Collins local amendments. 7. Plumbing code: a. International Plumbing Code (IPC), 2012. PART 2 PRODUCTS Not Used. PART 3 EXECUTION Not Used. END OF SECTION Page 74 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 75 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 01_60_00 PRODUCT REQUIREMENTS PART 1 GENERAL 1.01 SUMMARY A. Section includes: Product requirements; product selection; product options and substitutions; quality assurance; delivery, handling, and storage; and manufacturer’s instructions. B. Related sections: 1. Section 01_75_17 - Commissioning. 2. Section 01_78_23 - Operation and Maintenance Data. 1.02 DEFINITIONS A. Products: Inclusive of material, equipment, systems, shop fabrications, source quality control. 1.03 REFERENCES A. American National Standards Institute (ANSI). 1.04 PRODUCT REQUIREMENTS A. Comply with Specifications and referenced standards as minimum requirements. B. Provide products by same manufacturer when products are of similar nature, unless otherwise specified. C. Provide like parts of duplicate units that are interchangeable. D. Provide equipment that has not been in service prior to delivery, except as required by tests. E. When necessary, modify Supplier's standard product to conform to specified requirements or requirements indicated on the Drawings and contained in Laws and Regulations. F. Supplier shall have maintenance support facilities meeting the following requirements: 1. Minimum 5 years operational experience. 2. Location within the continental United States. 3. Equipment and tools capable of making repairs. 4. Staff qualified to make repairs. 5. Inventory of maintenance spare parts. Page 76 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 G. Material requirements: 1. Materials: Provide corrosion resistance suitable for project conditions. 2. Dissimilar metals: Separate contacting surfaces with dielectric material. PART 2 PRODUCTS 2.01 PRODUCT SELECTION A. When products are specified by standard or specification designations of technical societies, organizations, or associations only, provide products that meet or exceed reference standard and Specifications. B. When products are specified with names of manufacturers but no model numbers or catalog designations, provide: 1. Products by one of named manufacturers that meet or exceed Specifications. C. When products are specified with names of manufacturers and model numbers or catalog designations, provide: 1. Products with model numbers or catalog designations by one of named manufacturers. D. When products are specified with names of manufacturers, but with brand or trade names, model numbers, or catalog designations by one manufacturer only, provide: 1. Products specified by brand or trade name, model number, or catalog designation. 2. Products by one of named manufacturers proven in accordance with requirements for or equals to meet or exceed quality, appearance and performance of specified brand or trade name, model number, or catalog designation. E. When Products are specified with only one manufacturer followed by "or Equal," provide: 1. Products meeting or exceeding Specifications by specified manufacturer. 2.02 QUALITY ASSURANCE A. Employ entities that meet or exceed specified qualifications to execute the Work. B. Inspect conditions before executing subsequent portions of the Work. Accept responsibility for correcting unsatisfactory conditions upon executing subsequent portions of the Work. 2.03 SHIPMENT, HANDLING, STORAGE, AND PROTECTION A. Shipment (by Supplier): 1. Mandatory requirements prior to shipment of equipment: a. Engineer approved shop drawings. b. Engineer approved Manufacturer’s Certificate of Source Testing as specified in Section 01_75_17. c. Submit draft operations and maintenance manuals, as specified in Section 01_78_23. Page 77 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 2. Prepare products for shipment by: a. Tagging or marking products to agree with delivery schedule or shop drawings. b. Including complete packing lists and bills of material with each shipment. c. Packaging products to facilitate handling and protection against damage during transit, handling, and storage. d. Securely attach special instructions for proper field handling, storage, and installation to each piece of equipment before packaging and shipment. 3. Transport products by methods that avoid product damage. Equipment shall be contained within protective cover and shall be delivered on flatbed truck. 4. Supplier shall notify Contractor no later than forty-eight (48) hours prior to shipping equipment. B. Receiving (by Contractor): 1. Deliver products in undamaged condition in Supplier's unopened containers or packaging. C. Handling (by Contractor): 1. Handle equipment in accordance with Supplier's instructions. 2. Provide equipment and personnel to handle products by methods to prevent soiling or damage. 3. Upon delivery, promptly inspect shipments. a. Verify compliance with Contract Documents, correct quantities, and undamaged condition of products. b. Acceptance of shipment does not constitute final acceptance of equipment. D. Storage (by Contractor): 1. Immediately store and protect products and materials until installed in Work. 2. Store products with seals and legible labels intact. 3. Maintain products within temperature and humidity ranges required or recommended by manufacturer. 4. Protect painted surfaces against impact, abrasion, discoloration, and other damage. a. Repaint damaged painted surfaces. 5. Exterior storage of fabricated products: a. Place on aboveground supports that allow for drainage. b. Cover products subject to deterioration with impervious sheet covering. c. Provide ventilation to prevent condensation under covering. 6. Store moisture sensitive products in watertight enclosures. 7. Furnish covered, weather-protected storage structures providing a clean, dry, noncorrosive environment for all mechanical equipment, valves, architectural items, electrical and instrumentation equipment and special equipment to be incorporated into this project. a. Storage of equipment shall be in strict accordance with the “instructions for storage” of each equipment supplier and manufacturer including connection of heaters, placing of storage lubricants in equipment, etc. b. The Contractor shall furnish a copy of the manufacturer’s instructions for storage to the Engineer prior to storage of all equipment and materials. 8. Store loose granular materials on solid surfaces in well-drained area. Prevent materials mixing with foreign matter. Provide access for inspection. 9. Payment will not be made for improperly stored equipment and materials. Page 78 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 10. Provide equipment log including, as a minimum, the equipment identification, date stored, date of inspection/maintenance, date removed from storage, copy of manufacturer’s recommended storage guidelines, description of inspection/maintenance activities performed, and signature of party performing inspection/maintenance. E. Protection after installation (by Contractor): 1. Provide substantial coverings as necessary to protect installed products from damage from traffic and subsequent construction operations. a. Remove covering when no longer needed. 2.04 SPARE PARTS, MAINTENANCE PRODUCTS, AND SPECIAL TOOLS A. Provide spare parts, maintenance products, and special tools as required by Specifications. B. Box, tag, and clearly mark items. C. Contractor shall coordinate with Owner to determine appropriate location and facility onsite to store spare parts, maintenance products, and special tools in enclosed, weather-proof, and lighted facility during the construction period. D. Spare parts and special tools inventory list, see Appendix A: 1. Equipment tag number. 2. Equipment manufacturer. 3. Subassembly component, if appropriate. 4. Quantity. 5. Storage location. E. Large items: 1. Weight: Greater than 50 pounds. 2. Size: Greater than 24 inches wide by 18 inches high by 36 inches long. 3. Stored individually. 4. Clearly labeled: a. Equipment tag number. b. Equipment manufacturer. c. Subassembly component, if appropriate. F. Smaller items: 1. Weight: Less than 50 pounds. 2. Size: Less than 24 inches wide by 18 inches high by 36 inches long. 3. Stored in spare parts box. 4. Clearly labeled a. Equipment tag number. b. Equipment manufacturer. c. Subassembly component, if appropriate. G. Spare parts and special tools box: 1. Wooden box: a. Size: As required to contain spare parts and special tools. Page 79 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 2. Hinged wooden cover. a. Strap type hinges. b. Locking hasp. c. Spare parts inventory list taped to underside of cover. 3. Coating: Two coats of Carboline: Sanitile 120, or equal. 4. Clearly labeled: a. The words “Spare Parts and/or Special Tools”. b. Equipment tag number. c. Equipment manufacturer. PART 3 EXECUTION 3.01 COMMISSIONING A. As specified in Section 01_75_17. 3.02 CLOSEOUT ACTIVITIES A. Owner may request advanced delivery of spare parts, maintenance products, and special tools. 1. Deduct the delivered items from inventory and provide transmittal documentation. B. Immediately prior to the date of Substantial Completion, arrange to deliver spare parts, maintenance products, and special tools to Owner at a location on site chosen by the Owner. 1. Provide itemized list of spare parts and special tools that matches the identification tag attached to each item. 2. Owner and Engineer will review the inventory and the itemized list to confirm it is complete and in good condition prior to signing for acceptance. 3.03 ATTACHMENTS A. Appendix A - Spare Parts, Maintenance Products, and Special Tools Inventory List. END OF SECTION Page 80 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 APPENDIX A SPARE PARTS, MAINTENANCE PRODUCTS, AND SPECIAL TOOLS INVENTORY LIST Page 81 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SPARE PARTS, MAINTENANCE PRODUCTS, AND SPECIAL TOOLS INVENTORY LIST Owner: Date: Contractor: Project No.: Project Name: Inventory List Spec Number: Spec Title Equipment Tag No.: Equipment Manufacturer: Quantity Subassembly Component Description Manufacturer’s Part Number Storage Location Ownership Transition Date (Contractor to Owner) Ownership Transition Verification (Owner Signature) Page 82 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 83 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 01_75_17 COMMISSIONING PART 1 GENERAL 1.01 SUMMARY A. Section includes: Requirements for each Commissioning phase of the Project equipment/system and/or facility. B. Related sections: 1. Section 01_78_23 - Operation and Maintenance Data. 2. Section 26_12_20 - Liquid Filled Pad Mounted Transformers. 3. Section 26_24_14 - Group-Mounted Circuit Breaker Switchboards. 1.02 DEFINITIONS A. Clean Water Facility Testing – Testing of complete facility utilizing clean water for the purpose of confirming extended equipment/system operation prior to Process Start-up Phase. B. Commissioning – The process of planning, testing, and process start-up of the installation for compliance with contract requirements and demonstrating, through documented verification, that the project has successfully met the Contractual requirements. It includes training the Owner's staff to operate the facility. C. Commissioning Phases – The work activities of facility commissioning are grouped into the phases defined in the table below. Commissioning Planning Phase Testing and Training Phase Process Start-Up Phase Owner Training Plan and Schedule Source Testing Process Start-up Commissioning Schedule Owner Training Process Operational Period Subsystem Testing Plan Installation Testing Instrumentation and Controls Fine-Tuning Clean Water Facility Testing Plan Functional Testing Clean Water Facility Testing Closeout Documentation Page 84 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 D. Component – A basic building block of equipment, subsystems, and systems that requires installation or functional testing but does not have an electrical connection or internal electronics. (Examples: Process piping and manual isolation valves). E. Device – A basic building block of equipment, subsystems, and systems that requires installation or functional testing and does have an electrical connection or internal electronics. (Examples: Pump pressure transmitter, flow meter, etc.). F. Equipment – An assembly of component(s) and devices(s) that requires installation or functional testing. (Examples: Pump, motor, VFD, etc.). G. Facility – A grouping of process areas, systems, subsystems, equipment, components, and devices (Examples: Dewatering system, pump station, etc.). H. Functional Testing – Testing performed on a completed subsystem to demonstrate that equipment/system meets manufacturers’ calibration and adjustment requirements and other requirements as specified. Functional testing includes operating equipment/system manually in local, manually in remote (or remote manual), and automatically in remote (in remote auto). I. Installation Testing – Testing to demonstrate that subsystem component (piping, power, networks, devices, etc.) is ready and meets the project requirements in advance of functional testing. Installation testing also includes manufacturers’ certification of installation and other requirements as specified to prepare equipment/system for Functional Testing. Also referred to as Field Acceptance Testing. J. Instrumentation and Controls Fine-Tuning – Improving the performance of the Instrumentation Process Control system by operating for an extended time period. K. Manufacturer’s Certificate of Source Testing – When applicable, the form is used during Source Testing for the manufacturer to confirm that the applicable source tests have been performed and results conform to the Contract Documents. The form is provided at the end of this Section. L. Manufacturer’s Certificate of Installation and Functionality Compliance – The form is used during Installation Testing and Functional Testing. It is submitted at the end of Functional Testing to confirm that the equipment/system is installed in conformance with the Contract Documents and that it meets the Functional Testing requirements defined in the Contract Documents. The form is provided at the end of this Section. M. Process Area – A grouping of systems, subsystems, equipment, components, and devices that divide a facility into functional areas. N. Process Operational Period – A period of time after completion of the process start-up set aside for final Operational Testing to verify facility performance meets the Contract Document requirements. This period may specifically limit other construction activities. O. Process Start-up Phase - Operating the facility to verify performance meets the Contract Document requirements. Page 85 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 P. Process Start-Up – Activities conducted after the testing and training phase that are necessary to place systems or process areas into operational service. Q. Product – A system, subsystem, or component. R. Subsystem – A building block of systems made up from a grouping of components, devices, and equipment that perform a definable function. S. System – A grouping of subsystems, equipment, components, and devices that perform a definable function. 1.03 COMMISSIONING COORDINATION (CC) A. Contractor, Owner and Resident Engineer shall coordinate to provide commissioning coordination for the Project. B. CC responsibilities include the following: 1. Lead efforts relating to Commissioning. 2. Be thoroughly familiar with commissioning requirements in the Contract Documents. 3. Be regularly engaged and experienced in all aspects of commissioning. 4. Provide technical instruction for commissioning. 5. Provide primary interface with Engineer and Owner for efforts relating to Commissioning of Project facilities. 6. Coordinate training efforts. 1.04 SERVICES OF SUPPLIER’S REPRESENTATIVES A. Qualification of Supplier's representative as specified in the Contract Documents technical Sections include the following: 1. Authorized representative of the manufacturer, factory trained and experienced in the technical applications, installation, operation, and maintenance of respective equipment/system with full authority by the equipment/system manufacturer to issue the certifications required of the manufacturer. 2. Competent, experienced technical representatives of equipment/system manufacturer for assembly, installation, testing guidance, and training. 3. Additional qualifications may be specified in the individual Sections. 4. Submit qualifications of the manufacturer’s representative no later than 30 days in advance of required observations. 5. Representative subject to approval by Owner and Engineer. 6. No substitute representatives will be allowed until written approval by Owner and Engineer has been obtained. B. Completion of manufacturer on-site services: Engineer approval required. C. Manufacturer is responsible for determining the time required to perform the specified services. 1. Minimum times specified in the Contract Documents are estimates. 2. No additional costs associated with performing the required services will be approved. 3. Manufacturer required to schedule services in accordance with the Contractor’s project schedule up to and including making multiple trips to Page 86 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 project site when there are separate milestones associated with installation of each occurrence of manufacturer’s equipment. D. Manufacturer’s on-site services as specified in the Contract Documents include the following: 1. Assistance during Commissioning Phase and Process Start-Up Phase as indicated in the equipment specification. 2. Upon request, provide daily copies of manufacturer's representative's field notes and data to Engineer. 3. Other requirements as specified in the Contract Documents. 1.05 PLANNING PHASE A. Overview of Planning Phase: 1. Define approach and timing for Commissioning. 2. The Contractor shall be responsible for performing Planning Phase activities with assistance from Supplier as specified herein. B. Owner training plan and schedule: 1. Training outcomes: a. Owner’s operations, maintenance, and engineering staff have the information needed to safely operate, maintain, and repair the equipment/systems provided under this Contract. 2. Training objectives: a. To instruct personnel in the operation and maintenance of the equipment/system. Instruction shall include step-by-step troubleshooting procedures with all necessary test equipment/system. b. To instruct personnel in the removal, inspection, and cleaning of equipment/system as needed. c. Training tailored to the skills and job classifications of the staff attending the classes (e.g., plant superintendent, treatment plant operator, maintenance technician, electrician, etc.). d. Provide supporting documentation, such as vendor operation and maintenance manuals. 3. Training schedule: a. Owner’s staff training scheduled within the constraints of their workloads. Those who will participate in this training have existing full-time work assignments, and training is an additional assigned work task, therefore, scheduling is imperative. Operator training shall occur between 7:00 a.m. and 3:30 p.m., Monday through Friday. Maintenance staff training shall occur between 7:00 a.m. and 4:30 p.m. Monday through Thursday. 4. Training plan: a. Coordinate and arrange for manufacturer’s representatives to provide both classroom-based learning and field (hands-on) training, based on training module content and stated learning objectives. b. Conduct classroom training at location designated by Owner. c. Scope and sequence: 1) Plan and schedule training in the correct sequence to provide prerequisite knowledge and skills to trainees. a) Describe recommended procedures to check/test equipment/system following a corrective maintenance repair. Page 87 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 5. Training scheduling coordination: a. Complete Owner training no sooner than 15 calendar days prior to start of process start-up of each system. 6. Training sessions: a. Provide training sessions for equipment/system as specified in the individual equipment/system Section. 7. Schedule requirements: a. Provide detailed schedule of commissioning activities including durations and sequencing requirements. 1) Identify the following activities: a) Testing and Training Phase: (1) Source Testing. (2) Owner Training. (3) Installation Testing. (4) Functional Testing. (5) Clean Water Facility Testing. (6) Closeout Documentation. b) Process Start-Up Phase: (1) Process Start-Up. (2) Process Operational Period. (3) Instrumentation and Controls Fine-Tuning. b. Schedule manufacturer’s services to avoid conflict with other on-site testing or other manufacturers’ on-site services. c. Verify that conditions necessary to allow successful testing have been met before scheduling services. C. Subsystem testing plans: 1. Provide separate testing plans for each individual subsystem and system that include the following: a. Approach to testing including procedures, schedule, and recirculation requirements. b. Test objective: Demonstrate subsystem meets the design requirements as specified in the technical Sections. c. Test descriptions, forms, temporary systems (pumps, piping, etc.), shutdown requirements for existing systems, test forms, test logs, witness forms, and checklists to be used to control and document the required tests. d. Test forms: Include, but not limited to, the following information: 1) Tag and name of equipment/system to be tested. 2) Test date. 3) Names of persons conducting the test. 4) Names of persons witnessing the test, where applicable. 5) Test data. 6) Applicable project requirements. 7) Check offs for each completed test or test step. 8) Place for signature of person conducting tests and for the witnessing person, as applicable. e. Define start-up sequencing of unit processes: 1) Include testing of alarms, interlocks, permissives, control circuits, capacities, speeds, flows, pressures, vibrations, sound levels, and other parameters. Page 88 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 2) Provide detailed test procedures setting forth step-by-step descriptions of the procedures for systematic testing of equipment/system. 3) Demonstrate proper rotation, alignment, speed, flow, pressure, vibration, sound level, adjustments, and calibration. a) Perform initial checks in the presence of and with the assistance of the manufacturer’s representative. 4) Owner shall demonstrate proper operation of each control loop function including mechanical, electrical, alarms, local and remote controls, instrumentation, and other equipment/system functions. a) Generate signals with test equipment/system to simulate operating conditions in each control mode. 2. Engineer approval of test plan is required prior to performing test. a. Revise and update test plans based on review comments, actual progress, or to accommodate changes in the sequence of activities. b. Submit test reports for each phase of testing for each equipment/system. c. Engineer approval of preceding test reports is required prior to start of next test. d. Tests will be rescheduled if test plan is not approved by the required deadline. 3. Contractor is responsible to reproduce and distribute final test procedures. D. Clean Water Facility Testing Plan: 1. Submit a Clean Water Facility Testing Plan equivalent to the requirements of the subsystem test plans a minimum of 30 calendar days prior to Clean Water Facility Testing. 1.06 TESTING AND TRAINING PHASE A. Overview of Testing And Training Phase: 1. General: a. Include specified Source Testing, Owner Training, Installation Testing, Functional Testing, Clean Water Facility Testing, and Closeout Documentation required by this Section and the technical Sections. 2. Supplier responsibilities: a. Prior to testing, verify equipment protective devices and safety devices have been installed, calibrated, and tested. b. Acceptable tests: Demonstrate the equipment/system performance meets the requirements stated in the Contract Documents. 1) When the equipment/system fails to meet the specified requirements, perform additional, more detailed, testing to determine the cause, correct, repair, or replace the causative components and repeat the testing that revealed the deficiency. B. Source Testing (by Supplier): 1. Also referred to as factory testing or factory acceptance testing (FAT). 2. Test components, devices, and equipment/system for proper performance at point of manufacture or assembly as specified in the technical Sections. 3. Notify the Engineer in writing when the equipment/system is ready for source inspection and testing. 4. Source Test Plan (by Supplier): a. As specified in this Section and other technical Sections. Page 89 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 b. Source Testing requirements as specified in technical Sections. 1) Non-witnessed: Provide Manufacturer’s Certificate of Source Testing. 2) Witnessed: 2 Owner's representatives, 1 Engineer’s representative, and 1 Contractor representative present during testing, unless otherwise specified, and provide Manufacturer’s Certificate of Source Testing. c. Prepared by Supplier as a result of discussions and planning emerging from regularly conducted commissioning meetings for source tests as specified in the Contract Documents. d. Provide the following items for each Source Test: 1) Purpose and goals of the test. 2) Identification of each item of equipment/system, including system designation, location, tag number, control loop identifier, etc. 3) Description of the pass/fail criteria that will be used. 4) Listing of pertinent reference documents (Contract Documents and industry standards or Sections applicable to the testing). 5) Complete description, including drawings or photographs, of test stands and/or test apparatus. 6) Credentials of test personnel. 7) Descriptions of test equipment to be used, product information, and all appropriate calibration records for the test equipment. 8) Test set-up procedures. 9) Detailed step-by-step test procedures. a) The level of detail shall be sufficient for the resident engineer and contractor to be able to follow the steps and develop confidence that the tests were being performed as planned. b) All steps are significant, and all steps shall be included in the procedures. 10) Sample data logs and data recording forms. 11) Sample computations or analyses with the results in the same format as the final report to demonstrate how data collected will be used to generate final results. a) Complete disclosure of the calculation methodologies. b) Include a sample for each type of computation required for the test and analysis of the results. 12) Detailed outline of the Source Test report. 13) Sample test reports. e. Submit Source Test Plan and forms as specified in the technical Sections. 1) Submit a copy of the Source Test Plan at least 21 days before any scheduled test date. 2) Engineer approval of Source Test Plan required prior to beginning source testing. 3) Schedule the testing after approval of the test procedures submittal. f. Indicate the desired dates for source inspection and testing. 1) Notify the Engineer of the scheduled tests a minimum of 15 days before the date of the test. 5. Test results: a. Prepare and submit test results with collected data attached. 6. Owner is responsible for costs associated with Owner's representative witnessing Source Tests. 7. Supplier is responsible for providing fuel, chemicals, and other consumables needed for Source Testing. Page 90 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 C. Owner training (by Supplier): 1. Training instruction format: a. The training for operations and maintenance personnel shall be provided as one entity. b. Instructors shall apply adult education best practices, emphasizing learner participation and activity. c. Training delivery may include problem solving, question/answer, hands-on instruction, practice, evaluation/feedback tools, and lecture. d. Visual aids and hands-on practice sessions must support training objectives. e. Lecturing should be less than 30 percent of class time. f. Conduct hands-on instruction according to the following descriptions: 1) Present hands-on demonstrations of at least the following tasks: a) Proper start-up, shutdown, and normal and alternative operating strategies. b) Common corrective maintenance repairs for each group. c) Describe recommended procedures to check/test equipment/system following a corrective maintenance repair. 2) Use tools and equipment provided by manufacturer to conduct the demonstrations. a) Submit requests for supplemental assistance and facilities with the Contractor’s proposed lesson plans. 3) Contractor remains responsible for equipment disassembly or assembly during hands-on training situations involving equipment disassembly or assembly by Owner’s personnel. a) Provide written certification of proper equipment/system operation to Engineer after completion of hands-on training. 2. Class agenda: a. Include the following information in the agenda: 1) Instructor name. 2) Listing of subjects to be discussed. 3) Time estimated for each subject. 4) Allocation of time for Owner staff to ask questions and discuss the subject matter. 5) List of documentation to be used or provided to support training. b. Owner may request that particular subjects be emphasized and the agenda be adjusted to accommodate these requests. c. Distribute copies of the agenda to each student at the beginning of each training class. 3. Number of students: a. Estimated maximum class size: 15 persons. 1) Owner will determine the actual number of students. 2) Engineer will provide an estimated headcount 1 week prior to the class, so that the instructor can provide the correct number of training aids for students. 4. Instructor qualifications: a. Provide instructors completely knowledgeable in the equipment/system for which they are training. b. Provide instructor’s technical preparation and instructional technology skills and experience. Page 91 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 c. Sales representatives are not qualified instructors unless they possess the detailed operating and maintenance knowledge required for proper class instruction. d. If, in the opinion of the Owner, an appropriately knowledgeable person did not provide the scheduled training, such training shall be rescheduled and repeated with a suitable instructor. 5. Training aids: a. Instructors are encouraged to use audio-visual devices, P&IDs, models, charts, and so forth to increase the transfer of knowledge. b. Owner shall provide equipment (televisions, video recorder/player, computer, projectors, screens, easels, etc.) for each class. c. Instructor is responsible for confirming with Engineer and Owner in advance of each class that the classroom will be appropriate for the types of audiovisual equipment to be employed. 6. Classroom documentation: a. Trainees will keep training materials and documentation after the session. b. Operations and maintenance manuals, as specified in technical Sections: 1) Provide a minimum of 2 copies of final Engineer-approved operations and maintenance manuals as specified in Section 01_78_23 for use during the classroom instruction. 2) Owner reserves the right to delay training for a particular equipment item if the operations and maintenance manuals for that equipment are incomplete, inaccurate, or otherwise unsuitable for use by the Owner’s staff. 3) No contract extensions or extra costs will be allowed for training delays due to operations and maintenance manual submittal delays. c. Provide supplemental documentation handouts to support instruction. d. Training modules: 1) Provide a training module for each equipment category. 2) Divide each training module’s instructional content into discrete lesson plans. e. Lesson plans: 1) Provide performance-based learning objectives. 2) State learning objectives in terms of what the trainees will be able to do at the end of the lesson. 3) Define student conditions of performance and criteria for evaluating instructional success. a) Provide the following information: 4) Instruction lesson plan outlines for each craft. a) Provide specific components and procedures. 5) Minimum requirements: a) Hands-on demonstrations planned for the instructions. b) Cross-reference training aids. c) Planned training strategies such as whiteboard work, instructor questions, and discussion points or other planned classroom or field strategies. d) Attach handouts cross-referenced by section or topic in the lesson plan. e) Indicate duration of outlined training segments. Page 92 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 6) Provide maintenance instruction lesson plans including mechanical, instrumentation, and electrical aspects: a) Equipment operation: (1) Describe equipment’s operating (process) function and system theory. (2) Describe equipment’s fundamental operating principles and dynamics. (3) Identify equipment’s mechanical, electrical, and electronic components and features. (4) Identify support equipment associated with the operation of subject equipment. (5) Detail the relationship of each piece of equipment or component to the subsystems, systems, and process. (6) Cite hazards associated with the operations, exposure to chemicals associated with the component, or the waste stream handled by the component. (7) Specify appropriate safety precautions, equipment, and procedures to eliminate, reduce, or overcome hazards. b) Detailed component description: (1) Define Preventative Maintenance (PM) inspection procedures required on equipment in operation, spot potential trouble symptoms (anticipate breakdowns), and forecast maintenance requirements (predictive maintenance). (a) Review preventive maintenance frequency and task analysis table. (2) Identify each component function and describe in detail. (3) Where applicable, group relative components into subsystems. (4) Identify and describe in detail equipment safety features, permissive and controls interlocks. 7) Provide the following information in equipment troubleshooting lesson plans: a) Define recommended systematic troubleshooting procedures as they relate to specific craft problems. b) Provide component specific troubleshooting checklists as they relate to specific craft problems. 8) Provide the following information in equipment Corrective Maintenance (CM) troubleshooting lesson: a) Describe recommended equipment preparation requirements as they relate to specific craft problems. b) Identify and describe the use of any special tools required for maintenance of the equipment as they relate to specific craft problems. c) Describe component removal/installation and disassembly/assembly procedures for specific craft repairs. d) Perform at least 2 hands-on demonstrations of common corrective maintenance repairs. (1) Additional demonstrations may be required by the Owner. e) Describe recommended measuring instruments and procedures, and provide instruction on interpreting alignment measurements, as appropriate. Page 93 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 7. Class logistics: a. Delivery time minimum: 4 hours. b. Delivery time maximum: 8 hours. c. Schedule specific sessions: 1) Minimum of 30 days in advance to allow Owner staffing arrangements to take place. 2) At the times requested by the Owner, within the period 7 a.m. to 7 p.m. Monday through Friday. a) Times scheduled will be at Owner’s discretion. 3) Owner approval and confirmation required for session schedules. 4) Provide minimum of 1 session for each class unless otherwise noted. 8. Distribute Training Evaluation Form following each training session. a. Training Evaluation Form is included in this Section. b. Return completed Training Evaluation Forms to Owner’s designated training coordinator immediately after session is completed. c. Revise training sessions judged “Unsatisfactory” by a majority of attendees. 1) Conduct training sessions again until a satisfactory rating is achieved at no additional cost to Owner. The Contractor shall be responsible for all costs associated with repeated training sessions including costs for trainee time. 9. Submittals: a. Prior to the training session: 1) Instructor qualifications: 30 calendar days prior to initial training session. 2) Training course materials: 14 calendar days prior to initial training session. a) Training agenda, lesson plan, presentation, and handouts. b) Other audio-visual aids utilized during each training course. c) Format: Electronic submission. b. Post training session: 1) Training course materials: Due 14 calendar days after class completion. a) Video recordings (by Contractor). b) Class attendance sheet. c) Training agenda, final lesson plan, presentation, and handouts. d) Other audio-visual aids utilized during each training course. e) Provide materials for all sessions of the class in a single transmittal. f) Format: Electronic and 3 hard copies organized in notebooks, after incorporation of modifications as noted by Engineer or Owner. D. Installation Testing (by Contractor and Supplier): 1. Perform subsystem testing according to approved Subsystem Testing Plans. 2. Initiate the Manufacturer’s Certificate of Installation and Functionality Compliance for all equipment. a. Manufacturer’s Certificate of Installation and Functionality Compliance form is included in this Section. b. Manufacturer’s Certificate of Installation and Functionality Compliance certifies the equipment meets the following requirements: 1) Has been properly installed, adjusted, aligned, and lubricated. Page 94 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 2) Is free of any stresses imposed by connecting piping or anchor bolts. 3) Is able to be operated as necessary for Functional Testing. c. Form shall be submitted after completion of Functional Testing, as specified in this Section. 3. Perform mechanical equipment Installation Testing: As specified below and in individual equipment Sections: a. Remove rust preventatives and oils applied to protect equipment during construction. b. Flush lubrication systems and dispose of flushing oils. 1) Recharge lubrication system with lubricant recommended by manufacturer. c. Flush fuel system and provide fuel for testing and start-up. d. Install and adjust packing, mechanical seals, O-rings, and other seals. Replace defective seals. e. Remove temporary supports, bracing, or other foreign objects installed to prevent damage during shipment, storage, and erection. f. Check rotating machinery for correct direction of rotation and for freedom of moving parts before connecting driver. g. Perform cold alignment and hot alignment to manufacturer's tolerances. h. Adjust V-belt tension and variable pitch sheaves. i. Inspect hand and motorized valves for proper adjustment. 1) Tighten packing glands to ensure no leakage, but permit valve stems to rotate without galling. 2) Verify valve seats are positioned for proper flow direction. j. Tighten leaking flanges or replace flange gasket. 1) Inspect screwed joints for leakage. k. Install gratings, safety chains, handrails, shaft guards, and sidewalks prior to operational testing. l. Owner may perform some of the activities listed in this subsection (to be coordinated between Owner, Contractor, and Supplier). 4. Electrical devices and subsystems Installation Testing: As specified in the technical Sections. 5. Instrumentation devices and subsystems Installation Testing: As specified in the technical Sections. E. Functional Testing (by Contractor and Supplier in cooperation with Resident Engineer): 1. Perform subsystem testing according to approved Subsystem Testing Plan. 2. Notify the Engineer 5 days prior to when the Work is ready for Functional Testing. a. Perform testing in the presence of the Engineer. 3. Determine Functional Testing durations with Owner’s input. a. Target minimum Functional Test duration: 8 hours. 1) Identify equipment/system that cannot be tested for a minimum of 8 hours as specified in technical Sections. 4. Perform Functional Testing as specified in technical Sections. a. Perform Functional Testing in addition to the other tests specified in the technical Sections. b. Perform Functional Testing to demonstrate that the component equipment functions as an entire system in accordance with the design requirements. c. Perform Functional Testing to demonstrate that the unit process has operated in a manner necessary to demonstrate equipment/system Page 95 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 functions manually in local, manually in remote (or remote manual), and automatically in remote (in remote auto). d. Repair or replace parts that operate improperly and retest. e. Submit testing results as specified in the technical Sections to the Owner and Engineer for approval of Functional Testing results. 5. Provide completed Manufacturer’s Certificate of Installation and Functionality Compliance forms for all equipment. a. Manufacturer’s Certificate of Installation and Functionality Compliance form is included in this Section. b. Manufacturer’s Certificate of Installation and Functionality Compliance certifies the equipment/system meets the following requirements: 1) Is suitable for satisfactory full-time operation under full-load conditions. 2) Operates within the allowable limits for vibration and noise. 3) Electrical and instrumentation requirements: a) Electrical equipment, instrumentation, and control panels are properly installed, calibrated, and functioning. b) Electrical Installation Testing is complete, and test results have been approved by the Engineer. (1) Noted deficiencies have been corrected. (2) Relays, circuit breakers, and other protective devices are set. c) Control logic for start-up, shutdown, sequencing, interlocks, control, and emergency shutdown has been tested and is properly functioning. d) Motor control is calibrated and tested. F. Clean Water Facility Testing (by Contractor and Supplier): 1. Do not begin Clean Water Facility Testing until Engineer has approved submittals for Functional Testing requirements. 2. Test entire facility at the design flow for the largest single process or system train to ensure proper complete facility (equipment/system) flow and pressure performance. 3. Perform testing in the presence of the Engineer unless such presence is expressly waived in writing. 4. The purpose of Clean Water Facility Testing is to confirm extended equipment/system operation prior to process start-up. a. Testing shall occur for a minimum of 4 hours with all systems operational to the extent possible. G. Closeout documentation (by Contractor and Supplier): 1. Submittals: a. Provide records generated during Commissioning Phase of Project. 1) Required documents include but are not limited to: a) Training documentation. b) Manufacturer’s Certificate of Source Testing. c) Manufacturer’s Certificate of Installation and Functionality Compliance. d) Daily logs of equipment/system testing identifying tests conducted and outcome. e) Test forms and documentation. f) Functional Testing results. Page 96 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 g) Logs of time spent by manufacturer's representatives performing services on the job site. h) Equipment lubrication records. i) Electrical phase, voltage, and amperage measurements. j) Insulation resistance measurements. k) Bearing temperature measurements. 1.07 PROCESS START-UP PHASE A. Overview of Process Start-Up Phase: 1. Operating the facility to verify performance meets the Contract Document requirements. 2. Contractor and Supplier responsible for activities associated with Process Start-Up Phase. B. Process Start-Up: 1. Perform process start-up in the presence of the Engineer. 2. Pre-start-up activities: a. Commissioning Documentation and Data Review. b. Start-Up Go/No-Go Decision Criteria. c. Building and Fire Inspection Compliance Check. d. Process Start-Up Sequence Review. 1) Submit a Process Start-Up plan for review by Engineer. 2) Include the following: a) Pre-start-up activities. b) Process Start-Up. c) Process Operational Period. e. Description of Temporary Testing Arrangement, if applicable. f. Final Process Start-Up Forms and Documentations. g. Final Operational Testing Plan. 3. Control loop tuning (by Owner): a. Perform control loop tuning during system testing with clean water to the extent possible. 4. Process area start-ups. a. Process start-up individual process areas comprised of multiple interdependent systems where possible and beneficial to reduce complexity and risk of complete facility testing. b. Process area test flows may be limited by upstream and downstream process constraints (i.e., tank and basin volumes) and/or localized recirculation capabilities. 5. Facility-wide process start-up. a. Upon approved completion of pre-start-up activities, perform entire facility process start-up. 1) Owner shall complete control loop tuning during this phase of process start-up. 2) Continue process start-up operations until facility meets or exceeds the Contract requirements. b. Process control systems testing. 1) Test complete system instrumentation, controls and PLC, HMI, and LOI programming for the facility. Page 97 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 c. Remaining equipment/system tests: 1) Conduct remaining specified equipment/system performance tests that could not be performed during the Testing and Training Phase due to inter-system and/or treatment process dependencies. C. Process Operational Period: 1. Prior to beginning the Process Operational Period: a. Conformance with treatment standards is required prior to Operational Testing, if applicable. b. Correct any outstanding punch list items that are related to process operation prior to the Operational Testing. 2. Duration: Minimum of ten (10) calendar days. 3. Engineer will be present for process operational period unless such presence is expressly waived in writing. 4. Prove facility conformance with Contract Document requirements. 5. Contractor to provide: a. Specified start-up materials and operating supplies. b. Necessary craft of labor assistance, in the event of an emergency equipment failure requiring immediate attention (emergency is defined as a failure of function which precludes the further operation of a critical segment of or the whole of the Work) with a response time of not more than 4 hours from the time of notification. c. Manufacturer’s authorized representative to supervise placing equipment/systems in operation and provide guidance during Operational Testing per applicable Section. d. Necessary manufacturer’s representatives and operating supplies for retesting systems that fail to pass the initial Operational Testing due to deficiencies in products of workmanship at no additional cost to the Owner. e. List of 24-hour “on-call” representative supervisory persons who will monitor the Operational Testing and serve as liaison for the Engineer and Owner. 6. Owner will provide: a. Operations personnel for duration of test. 7. Prior to date of Substantial Completion of Installation, the following construction coordination shall occur. a. Owner staff will operate the completed Project construction. b. Entire system shall continuously meet performance requirements and shall operate without fault, failure, or defect for a continuous period. c. Individual equipment/system failures that are corrected within 24 hours and do not prevent the entire project from continuously satisfying the established operational requirements shall not require the consecutive day test to be restarted unless the failure recurs. d. Restart the consecutive test period for any of the following conditions: 1) Any failure of the complete Project construction to meet operational requirements. 2) When malfunctions or deficiencies cause shutdown or partial operation of the facility, or results in failure of the complete Project construction to meet operational requirements. Page 98 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 3) Any individual equipment/system failure that meets any of the following conditions: a) Requires more than 24 hours to correct, unless otherwise specified in technical specifications. b) Recurs within the 24-hour correction period requiring further correction. 4) Immediately correct defects in material, workmanship, or equipment/system which became evident during Operational Testing. PART 2 PRODUCTS Not Used. PART 3 EXECUTION Not Used. END OF SECTION Page 99 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 MANUFACTURER’S CERTIFICATE OF SOURCE TESTING OWNER EQPT/SYSTEM PROJECT NAME EQPT TAG NO. PROJECT NO. EQPT SERIAL NO. SPECIFICATION NO. SPECIFICATION TITLE Comments: I hereby certify Source Testing has been performed on the above-referenced equipment/system as defined in the Contract Documents, and results conform to the Contract Document requirements. Testing data is attached. Date of Execution: , 20 Manufacturer: Manufacturer’s Authorized Representative Name (print): (Authorized Signature) If applicable, Witness Name (print): (Witness Signature) Page 100 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 MANUFACTURER’S CERTIFICATE OF INSTALLATION AND FUNCTIONALITY COMPLIANCE OWNER EQPT/SYSTEM PROJECT NAME EQPT TAG NO. PROJECT NO. EQPT SERIAL NO. SPECIFICATION NO. SPECIFICATION TITLE I hereby certify that the above-referenced equipment/system has been: (Check Applicable) Installed in accordance with manufacturer’s recommendations. Inspected, checked, and adjusted. Serviced with proper initial lubricants. Electrical/instrumentation and mechanical connections meet quality and safety standards. All applicable safety equipment has been properly installed. Functionally tested. System has been performance tested, and meets or exceeds specified performance requirements. NOTES: Attach test results with collected data and test report. Attach written certification report prepared by and signed by the electrical and/or instrumentation subcontractor. Comments: I, the undersigned manufacturer’s representative, hereby certify that I am (i) a duly authorized representative of the manufacturer, (ii) empowered by the manufacturer to inspect, approve, and operate this equipment/system, and (iii) authorized to make recommendations required to ensure that the equipment/system furnished by the manufacturer is complete and operational, except as may be otherwise indicated herein. I further certify that all information contained herein is true and accurate. Date: , 20 Manufacturer: Manufacturer’s Authorized Representative Name (print): By Manufacturer’s Authorized Representative: (Authorized Signature) Page 101 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 COMMISSIONING TRAINING EVALUATION FORM EQUIPMENT/SYSTEM ITEM: VENDOR/MANUFACTURER: DATE: NAME OF REPRESENTATIVE: 1. Was representative prepared? Acceptable Unacceptable or N/A 2. Was an overview description presented? Acceptable Unacceptable or N/A 3. Were specific details presented for system Acceptable Unacceptable or N/A components? 4. Were alarm and shutdown conditions Acceptable Unacceptable or N/A clearly presented? 5. Were step-by-step procedures for starting, Acceptable Unacceptable or N/A stopping, and troubleshooting presented? 6. Were routine/preventative maintenance Acceptable Unacceptable or N/A items clearly identified? 7. Was the lubrication schedule (if any) Acceptable Unacceptable or N/A discussed? 8. Was the representative able to answer all Acceptable Unacceptable or N/A questions? 9. Did the representative agree to research Acceptable Unacceptable or N/A and answer unanswered questions? 10. Comments: 11. Overall Rating: Satisfactory Unsatisfactory Note: Sessions judged “Unsatisfactory” by a majority of attendees shall be revised and conducted again until a satisfactory rating is achieved. Page 102 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 COMMISSIONING ROLES AND RESPONSIBILITIES MATRIX NO. TASK OWNER CONTRACTOR ENGINEER Testing and Training Phase Source Testing 1 Source Testing Witness Lead Witness, Review Installation Testing 2 Electrical Conductor Testing No Action Lead Witness 3 Electrical Field Acceptance Tests No Action Lead Witness 4 Instrument Field Calibration No Action Lead Witness 5 Network Installation Testing Witness Lead Witness 6 Loop Testing Witness Lead Witness 7 Pressure Testing No Action Lead Witness 8 Leak Testing No Action Lead Witness 9 Holiday Testing No Action Lead Witness 10 HVAC Testing No Action Lead Witness 11 Motor Electrical Testing No Action Lead Witness Functional Testing 12 Network Operational Testing Witness Lead Review 13 Preliminary Run Testing Local/Manual Control Witness Lead Review 14 PCIS Functional Demonstration Testing - Local/Auto Control Testing - Remote/Manual Contact Testing - Alarm Testing - Control Loop Testing (Owner) Witness Lead Review 15 Subsystem Start-Up and Testing Witness Lead Review 16 Equipment/System Start-Up and Testing Witness Lead Review 17 HVAC Start-Up and Testing Witness Lead Review 18 Wide Area Network Communications Testing Support Lead Witness 19 Manufacturer’s Certificate of Installation and Functionality Compliance No Action Lead Witness, Review Clean Water Facility Testing 20 Test Plan Finalization Support Lead Review 21 Clean Water Facility Testing Witness Lead Witness, Review Page 103 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 NO. TASK OWNER CONTRACTOR ENGINEER Process Start-Up Phase Process Start-Up 22 Commissioning Documentation and Data Review Review Support Lead 23 Start-Up Go/No-Go Decision Criteria Lead Support Review 24 Building and Fire Inspection Compliance Check No Action Lead Witness 25 HVAC Functionality Check No Action Lead Witness 26 Start-Up Sequence Review Support Lead Review 27 Temporary Testing Arrangement Finalization Support Lead Support 28 Start-Up Forms Finalization Support Lead Support 29 Operation Testing Plan Finalization Review Support Lead 30 Test Plan Finalization Support Lead Review 31 System Testing Support Lead Witness 32 Control Loop Tuning Lead Support Witness 33 Process Area Start-Ups Support Lead Witness 34 Facility-Wide Start-Up Support Lead Witness 35 Process Control Systems Testing Support Lead Witness 36 HVAC Final Testing, Adjust, and Balancing Witness Lead Witness, Review Process Operational Period 37 Operational Testing Support Lead Witness, Review 38 Final Testing Reports Support Lead Review Instrumentation and Controls Reliability Phase Instrumentation and Controls Reliability Period 39 As specified Legend: Lead: Primarily responsible for organization, coordination, and execution of task work product or result. Support: Assist the lead with organization, coordination, and execution of task work product or result. Witness: Observe and document completion of task work product or result. Review: As necessary to accept task work product result. No Action: Limited or no involvement. Page 104 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 105 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 01_78_23 OPERATION AND MAINTENANCE DATA PART 1 GENERAL 1.01 SUMMARY A. Section includes: Preparation and submittal of Operation and Maintenance Manuals. B. Related sections: 1. Section 46_21_90 - Pressurized In-Line Sludge Screen. 2. Section 46_05_94 - Mechanical Equipment Testing. 1.02 SUBMITTALS A. Submit Operation and Maintenance Manuals before field quality control testing and before training of each piece of equipment or system. B. Submit manuals for each piece of equipment or system. 1. Submit Manuals electronically until all comments from Owner and Engineer have been incorporated. Indicate section and tab divisions on electronic Manuals. 2. Provide one (1) hard copy of final manuals. 3. Make manuals available at project site for use by construction personnel and Owner. 4. Make additions and revisions to the Manuals in accordance with Owner's review comments. 1.03 OPERATION AND MAINTENANCE MANUALS A. Preparation: 1. Provide Operations and Maintenance Manuals in 3-ring binders with rigid covers. Utilize numbered tab sheets to organize information. 2. Provide original and clear text on reproducible non-colored paper. 3. Provide all dimensions in English units. 4. Coordinate with Contractor to define Operations and Maintenance Manual compliance with Owner's Computer Maintenance Management System (CMMS). B. Contents of Operation and Maintenance Manuals: 1. Cover page: Equipment name, equipment tag number, project name, Owner's name, appropriate date. Manufacturer's name, address, phone number, and email address. Local Representative's name, address, phone number, and email address. Contractor's name, address, phone number, and email address. Spare Parts Supplier name, address, phone number, and email address. 2. Table of Contents: General description of information provided within each tab section. Page 106 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 3. Equipment Summary Form: Completed form in the format shown in Appendix A. The manufacturer's standard form will not be acceptable. 4. Instrumentation Data Sheet. 5. Information from submittal that specifically applies to that equipment – i.e., pump curves, shop drawing with final dimensions. 6. Lubrication information: Required lubricants and lubrication schedules. 7. Control diagrams: a. Internal and connection wiring, including logic diagrams, wiring diagrams for control panels, ladder logic for computer based systems, and connections between existing systems and new additions, and adjustments such as calibrations and set points for relays, and control or alarm contact settings. b. Complete set of control schematics. 8. Programming: Copies of all Supplier furnished programming. 9. Start-up procedures: Recommendations for installation, adjustment, calibration, and troubleshooting. 10. Operating procedures: a. Step-by-step procedures for starting, operating, and stopping equipment under specified modes of operation. b. Include safety precautions and emergency operating shutdown instructions. 11. Preventative maintenance procedures: Recommended steps and schedules for maintaining equipment. 12. Overhaul instructions: Directions for disassembly, inspection, repair, and reassembly of the equipment; safety precautions; and recommended tolerances, critical bolt torques, and special tools that are required (highlighted). 13. Parts list: a. Complete parts list for all equipment being provided. b. Catalog data for all products or equipment furnished including generic title and identification number of each component part of equipment. 1) Include bearing manufacturer, model and ball or roller pass frequencies for every bearing. 14. Spare parts list: Recommended number of parts to be stored at the site and special storage precautions. 15. Drawings: a. Exploded view or plan and section views with detailed callouts. b. Provide electrical and instrumentation schematic record drawings. 16. Source (factory) quality control test results: Provide copies of factory test reports as specified in Section 46_05_94 or the equipment section. 17. Field quality control test results: After field-testing is completed, insert field test reports as specified in Section 46_05_94 or the equipment section. 18. Control Description and Final Start-Up checklist, plus any tests completed by the manufacturer. 19. Certificate of proper installation. Page 107 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 PART 2 PRODUCTS Not Used. PART 3 EXECUTION Not Used. END OF SECTION Page 108 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 APPENDIX A EQUIPMENT SUMMARY FORM 1. EQUIPMENT ITEM 2. EQUIPMENT IDENTIFICATION NUMBER(S) (maps equipment number) 3. LOCATION OF EQUIPMENT 4. P&ID Tag, Make, Model, Serial No. 5. NAMEPLATE DATA Manufacturer Horsepower Amperage Voltage Service Factor (S.F.) Speed ENC Type Capacity Other 6. MANUFACTURER'S LOCAL REPRESENTATIVE Manufacturer Name Address Telephone Number 7. MAINTENANCE REQUIREMENTS (include page number inside O&M) 8. LUBRICANT LIST (include page number inside O&M) 9. SPARE PARTS (recommendations) (include page number inside O&M) 10. COMMENTS Page 109 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 01_78_36 WARRANTIES AND BONDS PART 1 GENERAL 1.01 SUMMARY A. Section includes: Warranty and bonds requirements. 1.02 SUBMITTALS A. For each item of material or equipment furnished under the Contract: 1. Submit form of manufacturer's warranty prior to fabrication and shipment of the item from the manufacturer's facility. 2. Submit form of manufacturer's special warranty when specified. B. Provide consolidated warranties and bonds within 15 calendar days of Substantial Completion. 1. Contents: a. Organize warranty and bond documents: 1) Include Table of Contents organized by specification Section number and the name of the product or work item. b. Include each required warranty and bond in proper form, with full information, are certified manufacturer as required, and are properly executed by Contractor, or subcontractor, supplier, or manufacturer. c. Provide name, address, phone number, and point of contact of manufacturer, supplier, and installer, as applicable. 2. Hardcopy format: a. Submit 2 copies. b. Assemble in 3 D-side ring binders with durable cover. c. Identify each binder on the front and spine with typed or printed title "Warranties and Bonds"; Project Name or Title, and the Name Address and Telephone Number of the Contractor. 3. Electronic copy in PDF format. a. Submit 1 copy. 1.03 OWNER'S RIGHTS A. Owner reserves the right to reject warranties. B. Owner reserves the right to refuse to accept Work for the project if the required warranties have not been provided. Page 110 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 1.04 RELATIONSHIP TO GENERAL WARRANTY AND CORRECTION PERIOD A. Warranties specified for materials and equipment shall be in addition to, and run concurrent with, both Contractor's general warranty and the correction period requirements. B. Disclaimers and limitations in specific materials and equipment warranties do not limit Contractor's general warranty, nor does such affect or limit Contractor's performance obligations under the correction period. 1.05 MANUFACTURER'S WARRANTY MINIMUM REQUIREMENTS A. Written warranty issued by item's manufacturer. B. Project-specific information, properly executed by product manufacturer, and expressly states that its provisions are for the benefit of the Owner. C. Covers all costs associated with the correction of the defect, including but not limited to removal of defective parts, new parts, labor, and shipping. 1. When correcting warranted Work that has failed, remove and replace other Work that had been damaged as a result of such failure or that must be removed and replaced to provide access for correction of warranted Work. D. Provides a timely response to correct the defect. 1. Manufacturer shall provide, in a timely fashion, temporary equipment as necessary to replace warranted items requiring repair or replacement, when warranted items are in use and are critical to the treatment process, as defined by Owner. 2. In the case that Owner has to provide temporary equipment to replace function of warranted item requiring repair or replacement, manufacturer shall reimburse Owner for such costs associated with the temporary equipment. E. Warranty commence running on the date of substantial completion. 1. For items of Work for which acceptance is delayed beyond Date of Substantial Completion, submit warranty within 10 calendar days after acceptance, listing date of acceptance as beginning of warranty period. F. Duration of Warranty: 2 years. 1.06 MANUFACTURER'S SPECIAL WARRANTY A. Manufacturer's special warranty is a written warranty published by the manufacturer which includes the requirements specified in the Section where the item is specified. 1. Includes Project-specific information and requirements, properly executed by product manufacturer, and expressly states that its provisions are for the benefit of the Owner. Technical sections indicate Project-specific requirements that differ from the minimum warranty requirements for that item. a. Examples include extending the duration of manufacturer's warranty or to provide increased rights to Owner. 2. Manufacturer's warranties commence on the date that the associated item is certified by Engineer as substantially complete. Page 111 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 1.07 WARRANTY WORK A. Contractor's responsibilities: 1. Manufacturer's disclaimers and limitations on product warranties do not relieve the Contractor of the warranty on the work that incorporates the product, nor does it relieve suppliers, manufacturers, and subcontractors required to countersign special warranties with Contractor. B. Replacement cost: 1. Upon determination that work covered by warranty has failed, replace or rebuild the work to an acceptable condition complying with requirement of the Contract Documents. a. Contractor is responsible for the cost of replacing or rebuilding defective work regardless of whether Owner has benefited from the use of the work through a portion of its anticipated useful service life. C. Related damages and losses: 1. When correcting warranted work that has failed, remove and replace other work that has been damaged as a result of such failure or that must be removed and replaced to provide access for correction of warranted work. D. Owner's recourse: 1. Written warranties are in addition to implied warranties, and shall not limit the duties, obligations, rights, and remedies otherwise available under the law, nor shall warranty periods be interpreted as limitation on time in which Owner can enforce such other duties, obligations, rights, or remedies. E. Reinstatement of warranty: 1. When work covered by a warranty has failed and has been corrected by replacement or rebuilding, reinstate the warranty by written endorsement. a. The reinstated warranty shall be equal to the original warranty with an equitable adjustment for depreciation. 1.08 IMPLIED WARRANTIES A. Warranty of title and intellectual rights: 1. Except as may be otherwise indicated in the Contract Documents, implied warranty of title required by Laws and Regulations is applicable to the Work and to materials and equipment incorporated therein. 2. Provisions on intellectual rights, including patent fees and royalties, are in the General Conditions, as may be modified by the Supplementary Conditions. B. Implied warranties: Duration in accordance with Laws and Regulations. 1.09 BONDS A. Bond requirements as specified in the technical sections. B. Bonds commence running on the date of substantial completion. 1. For items of Work for which acceptance is delayed beyond Date of Substantial Completion, submit warranty within 10 calendar days after acceptance, listing date of acceptance as beginning of bond period. Page 112 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 PART 2 PRODUCTS Not Used. PART 3 EXECUTION Not Used. END OF SECTION Page 113 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 01_81_01 PROJECT DESIGN CRITERIA PART 1 GENERAL 1.01 SUMMARY A. Section includes: Project design criteria such as temperature and site elevation. 1.02 PROJECT DESIGN CRITERIA A. All equipment and materials for the project are to be suitable for performance in wastewater treatment plant environment and under following conditions: 1. Design temperatures are: a. Design Outdoor temperatures: -5 to 97 degrees Fahrenheit. b. Indoor temperatures for the following buildings: 1) Electrical rooms: 50 to 85 degrees Fahrenheit. 2. Moisture conditions: Defined in individual equipment sections. 3. Site elevation: Approximately 4,885 feet above mean sea level. PART 2 PRODUCTS Not Used. PART 3 EXECUTION Not Used. END OF SECTION Page 114 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 115 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 01_81_02 SEISMIC DESIGN CRITERIA PART 1 GENERAL 1.01 SUMMARY A. Section includes: Seismic design criteria for the following: 1. Anchorage of mechanical and electrical equipment. 2. Seismic design and design of anchorage for small tanks fabricated off site and shipped to the Project site. 3. Other structures or items as specified or indicated on the Drawings. B. Related sections: 1. Section 01_41_00 - Regulatory Requirements. 1.02 REFERENCES A. American Society of Civil Engineers (ASCE): 1. 7-10 - Minimum Design Loads for Buildings and Other Structures. 1.03 SYSTEM DESCRIPTION A. Design in accordance with the requirements of the building code as specified in Section 01_41_00: B. Design spectral acceleration at short period, SDS: 0.143. C. Design spectral acceleration at 1 second period, SD1: 0.065. D. Design of non-structural components and their connections to structures: 1. Component amplification factor, ap: In accordance with ASCE 7, Tables 13.5-1 and 13.6-1. 2. Component response modification factor, Rp: In accordance with ASCE 7, Tables 13.5-1 and 13.6-1. 3. Component importance factor, Ip: Table 1: Component importance factor, Ip Component Description Ip Electrical Equipment and appurtenances provided and installed under Division 26. 1.5 E. Seismic Design Category (SDC) for certification of mechanical and electrical equipment as required by ASCE 7: 1. All areas: Seismic Design Category A. Page 116 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 F. Design requirements: Anchorage of equipment to structures. 1. Do not use friction to resist sliding due to seismic forces. Do not design or provide connections that use friction to resist seismic loads. Resist seismic forces through direct tension and/or shear on anchors and fasteners. 2. Do not use more than 60 percent of the weight of the mechanical and electrical equipment for designing anchors for resisting overturning due to seismic forces. 3. Do not use more than 60 percent of the weight of the tank for resisting overturning due to seismic forces. 4. Anchoring and fastening to concrete and masonry: a. Provide anchors specified in Sections 03_21_17 and 05_05_24. b. Use only cast-in anchors (anchor bolts or welded studs) for anchors at connections that resist seismic forces. c. Do not use concrete anchors, flush shells, sleeve anchors, screw anchors, powder actuated fasteners, or other types of post-installed mechanical anchors unless indicated on the Drawings or accepted in writing by the Engineer. 1.04 SUBMITTALS A. Shop drawings and calculations: Complete shop drawings and seismic calculations. B. Calculations shall be signed and stamped by a civil or structural engineer licensed in the state where the Project is located. PART 2 PRODUCTS Not Used. PART 3 EXECUTION Not Used. END OF SECTION Page 117 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 01_81_04 WIND DESIGN CRITERIA PART 1 GENERAL 1.01 SUMMARY A. Section includes: Wind design criteria. B. Related sections: 1. Section 01_41_00 - Regulatory Requirements. 1.02 SYSTEM DESCRIPTION A. Design requirements: 1. Building code criteria: Design for wind in accordance with building code as specified in Section 01_41_00: a. Risk category: III. b. Wind speed, Vult: 135 miles per hour. c. Wind speed, Vasd: 105 miles per hour. d. Exposure category: C. e. Topographic factor, Kzt: 1.0. 2. Resist wind forces through direct bearing on anchors and fasteners. Do not design or provide connections that use friction to resist wind loads. 3. Anchoring and fastening to concrete and masonry: a. Use only cast-in and built-in anchors (anchor bolts and welded studs) for anchors at connections that resist wind forces. b. Do not use concrete anchors, flush shells, sleeve anchors, flush shells, screw anchors, powder actuated fasteners, or other types of post-installed mechanical anchors unless indicated on the Drawings or accepted in writing by the Engineer. 1.03 SUBMITTALS A. Shop drawings and calculations: Complete shop drawings and wind design calculations. B. Calculations shall be signed and stamped by a civil or structural engineer licensed in the state where the Project is located. PART 2 PRODUCTS Not Used. PART 3 EXECUTION Not Used. END OF SECTION Page 118 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 119 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 26_05_00 COMMON WORK RESULTS FOR ELECTRICAL PART 1 GENERAL 1.01 SUMMARY A. Section includes: 1. General requirements applicable to all Electrical Work. 2. General requirements for electrical submittals. B. Related sections: 1. Section 01_33_00 - Submittal Procedures. 2. Section 01_60_00 - Product Requirements. 3. Section 01_75_17 - Commissioning. 4. Section 01_78_23 - Operation and Maintenance Data C. Interfaces to equipment, instruments, and other components: 1. The Drawings, Specifications, and overall design are based on preliminary information furnished by various equipment manufacturers which identify a minimum scope of supply from the manufacturers. This information pertains to, but is not limited to, instruments, control devices, electrical equipment, packaged mechanical systems, and control equipment provided with mechanical systems. 2. Provide all material and labor needed to install the actual equipment furnished, and include all costs to add any additional conduit, wiring, terminals, or other electrical hardware to the Work, which may be necessary to make a complete, functional installation based on the actual equipment furnished: a. Make all changes necessary to meet the manufacturer’s wiring requirements. 3. Review the complete set of Drawings and Specifications in order to ensure that all items related to the electrical power and control systems are completely accounted for. Include any such items that appear on the Drawings or in the Specifications from another discipline in the scope of Work: a. If a conflict between Drawings and Specifications is discovered, refer conflict to the Engineer as soon as possible for resolution. D. All electrical equipment and systems for the entire Project must comply with the requirements of the Electrical Specifications, whether referenced in the individual Equipment Specifications or not: 1. The requirements of the Electrical Specifications apply to all Electrical Work specified in other sections. 2. Inform all vendors supplying electrical equipment or systems of the requirements of the Electrical Specifications. 3. Owner is not responsible for any additional costs due to the failure of Contractor to notify all subcontractors and suppliers of the Electrical Specifications requirements. Page 120 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 E. Contract Documents: 1. General: a. The Drawings and Specifications are complementary and are to be used together in order to fully describe the Work. 2. Specifications: a. The General and Supplementary Conditions of the Contract Documents govern the Work. b. These requirements are in addition to all General Requirements. 3. Contract Drawings: a. The Electrical Drawings show desired locations, arrangements, and components of the Electrical Work in a diagrammatic manner. b. Locations of equipment, control devices, instruments, boxes, panels, etc. are approximate only; exercise professional judgment in executing the Work to ensure the best possible installation: 1) The equipment locations and dimensions indicated on the Drawings are approximate. Use the shop drawings to determine the proper layout, foundation, and pad requirements, etc. for final installation. Coordinate with all subcontractors to ensure that all electrical equipment is compatible with other equipment and space requirements. Make changes required to accommodate differences in equipment dimensions. 1.02 REFERENCES A. Code compliance: 1. As specified in Section 01_41_00. 2. The publications are referred to in the text by the basic designation only. The latest edition accepted by the Authority Having Jurisdiction of referenced publications in effect at the time of the bid governs. 3. The standards listed are hereby incorporated into this Section. a. American National Standards Institute (ANSI). b. American Society of Civil Engineers (ASCE): 1) ASCE 7 - Minimum Design Loads for Buildings and Other Structures. c. ASTM International (ASTM). d. Illuminating Engineering Society (IES). e. Institute of Electrical and Electronics Engineers (IEEE). f. Insulated Cable Engineers Association (ICEA). g. International Code Council (ICC). 1) International Code Council Evaluation Service (ICC-ES). a) AC 156 – Acceptance Criteria for Seismic Certification by Shake Table Testing of Non-Structural Components (ICC-ES AC 156). h. International Society of Automation (ISA). i. National Electrical Manufacturers Association (NEMA): 1) 250 - Enclosures for Electrical Equipment (1000 V Maximum). j. National Fire Protection Association (NFPA): 1) 70 - National Electrical Code (NEC). k. National Institute of Standards and Technology (NIST). l. Underwriters' Laboratories, Inc. (UL). Page 121 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 1.03 DEFINITIONS A. Definitions of terms and other electrical and instrumentation considerations as set forth by: 1. IEEE. 2. NETA. 3. IES. 4. ISA. 5. NEC. 6. NEMA. 7. NFPA. 8. NIST. B. Specific definitions: 1. FAT: Factory acceptance test. 2. ICSC: Instrumentation and controls subcontractor. 3. LCP: Local control panel: Operator interface panel that may contain an HMI, pilot type control devices, operator interface devices, control relays, etc. and does not contain a PLC or RIO. 4. PCM: Process control module: An enclosure containing any of the following devices: PLC, RTU, or RIO. 5. PCIS: Process control and instrumentation system. 6. Space: That portion of the switchgear, motor control center, panelboard, switchboard or control panel that does not physically contain a device but is capable of accepting a device with no modifications to the equipment, i.e., provide all standoffs, bus, and hardware, as part of the space. 7. Spare: That portion of the switchgear, motor control center, panelboard, switchboard or control panel that physically contains a device with no load connections to be made. 8. VCP: Vendor control panel: Control panels that are furnished with particular equipment by a vendor other than the ICSC. These panels may contain PLCs, RIO, OIT, HMI, etc. 9. Unequipped space: That portion of the switchgear, motor control center, panelboard, switchboard or control panel that does not physically contain a device, standoff, bus, hardware, or other equipment. 1.04 SYSTEM DESCRIPTION A. General requirements: 1. The Work includes everything necessary for and incidental to executing and completing the Electrical Work indicated on the Drawings and specified in the Specifications and reasonably inferable there from. B. New system: 1. 1,000 kVA pad mount transformer. 2. Outdoor, NEMA 3R switchboard with ratings and components as shown in the drawings. Page 122 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 C. Operating facility: 1. The Drake WRF is an operating facility. Portions of this facility must remain fully functional throughout the entire construction period. In consideration of this requirement, comply with the following guidelines: a. All outages must be of minimal duration and fully coordinated and agreed to by the Owner. b. As weather and water demand conditions dictate, re-adjust the construction schedule to meet the demands placed upon Owner by its users. c. Testing and start-up must be coordinated with site discharge requirements. 1.05 SUBMITTALS A. Furnish submittals as specified in Section 01_33_00 and this Section. B. General: 1. Instruct all equipment suppliers of submittals and operation and maintenance manuals of the requirements in this Section. 2. Furnish the submittals required by each section in the Electrical Specifications. 3. Adhere to the wiring numbering scheme specified in Section 26_05_53 throughout the Project: a. Uniquely number each wire. b. Wire numbers must appear on all Equipment Drawings. 4. Use equipment and instrument tags, as indicated on the Drawings, for all submittals. C. Submittal organization: 1. First page: a. Specification section reference. b. Name and telephone number of individual who reviewed submittal before delivery to Engineer. c. Name and telephone number of individual who is primarily responsible for the development of the submittal. d. Place for Contractor’s review stamp and comments. 2. Next pages: a. Provide confirmation of specification compliance: 1) Specification section: Include with each submittal a copy of the relevant specification section. a) Indicate in the left margin, next to each pertinent paragraph, either compliance with a check (√) or deviation with a consecutive number (1, 2, 3). b) Provide a list of all numbered deviations with a clear explanation and reason for the deviation. b. Include a response in writing to each of the Engineer’s comments or questions for submittal packages which are re-submitted: 1) In the order that the comments or questions were presented throughout the submittal. 2) Referenced by index section and page number on which the comment appeared. Page 123 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 3) Acceptable responses to Engineer’s comments are either: a) Engineer’s comment or change is accepted and appropriate changes are made. b) Explain why comment is not accepted or requested change is not made. c) Explain how requirement will be satisfied in lieu of comment or change requested by Engineer. 4) Any re-submittal, which does not contain responses to the Engineer’s previous comments shall be returned for Revision and Re-submittal. 5) No further review by the Engineer will be performed until a response for previous comments has been received. 3. Remaining pages: a. Actual submittal data: 1) Organize submittals in exactly the same order as the items are referenced, listed, and/or organized in the specification section. 2) For submittals that cover multiple devices used in different areas under the same specification section, the submittal for the individual devices must list the area where the device is intended to be used. D. Operation and maintenance manuals: 1. As specified in Section 01_78_23. 2. Furnish the Engineer with a complete set of written operation and maintenance manuals 8 weeks before Functional Acceptance Testing. E. Material and equipment schedules: 1. Furnish a complete schedule and/or matrix of all materials, equipment, apparatus, and luminaries that are proposed for use: a. Include sizes, names of manufacturers, catalog numbers, and such other information required to identify the items. F. Test reports: 1. As specified in Section 01_33_00. 2. Additional requirements for field acceptance test reports are specified in Section 01_75_17. G. Calculations: 1. Where required by specific Electrical Specifications: a. Because these calculations are being provided by a registered professional engineer, they will be reviewed for form, format, and content but will not be reviewed for accuracy and calculation means. 1.06 QUALITY ASSURANCE A. Furnish all equipment listed by and bearing the label of UL or of an independent testing laboratory acceptable to the Engineer and the Authority Having Jurisdiction. 1.07 DELIVERY, STORAGE, AND HANDLING A. As specified in Section 01_60_00. B. Shipping precautions: 1. After completion of shop assembly and successful factory testing, pack all equipment in protective crates, and enclose in heavy duty polyethylene Page 124 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 envelopes or secured sheeting to provide complete protection from damage, dust, and moisture. 2. Place dehumidifiers, when required, inside the polyethylene coverings. 3. Skid-mount the equipment for final transport. 4. Provide lifting rings for moving without removing protective covering. 5. Display boxed weight on shipping tags together with instructions for unloading, transporting, storing, and handling at the job site. C. Special instructions: 1. Securely attach special instructions for proper field handling, storage, and installation to each piece of equipment before packaging and shipment. 1.08 PROJECT OR SITE CONDITIONS A. Site conditions: 1. Provide an electrical, instrumentation and control system, including all equipment, raceways, and any other components required for a complete installation that meets the environmental conditions for the Site as specified in the General Requirements and below. 2. Altitude, temperature and humidity: a. Provide all electrical components and equipment fully rated for continuous operation at this altitude, with no additional derating factors applied. b. Provide additional temperature conditioning equipment to maintain all equipment in non-conditioned spaces subject to these ambient temperatures, with a band of 10 degrees Fahrenheit above the minimum operating temperature and 10 degrees Fahrenheit below maximum operating temperature, as determined by the equipment manufacturer’s guidelines: 1) Provide all power conduits wiring for these devices (e.g., heaters, fans, etc.) whether indicated on the Drawings or not. B. Provide enclosures for electrical, instrumentation and control equipment, regardless of supplier or subcontractor furnishing the equipment, that meet the requirements outlined in NEMA Standard 250 for the following types of enclosures: 1. NEMA Type 1: Intended for indoor use, primarily to provide a degree of protection from accidental contact with energized parts or equipment. 2. NEMA Type 4: Intended for indoor or outdoor use, primarily to protect equipment from exposure to windblown dust and rain, splashing or hose directed water, ice formation, and freezing. 3. NEMA Type 4X: Made from corrosion resistant materials (fiberglass reinforced plastic, 316 stainless steel or equal) and are intended for indoor or outdoor use, primarily to protect equipment from exposure to windblown dust and rain, splashing or hose directed water, ice formation and freezing, and corrosion. 4. NEMA Type 12: Intended for indoor use, primarily to provide a degree of protection from dust, falling dirt and dripping non-corrosive liquids. 5. NEMA Type 6: Rated for submergence. 6. NEMA Type 6P: Rated for prolonged submergence. 1.09 SCHEDULING A. General: 1. As specified in Sections 01_31_19 and 01_75_17. Page 125 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 2. Testing requirements are specified in Sections 01_75_17, 26_08_50 and other sections. 3. Commissioning and Process Start-up requirements as specified in Section 01_75_17. B. Pre-submittal conference: 1. Before producing any submittals, schedule a pre-submittal conference for the purposes of reviewing the entire Project, equipment, control philosophy, schedules, and submittal requirements. 2. Contractor, electrical subcontractor, all suppliers, and individual equipment manufacturers furnishing major pieces of equipment must attend. C. Factory acceptance testing (FAT): 1. Where FAT is required for equipment covered by these Specifications, notify the Engineer in writing when the equipment is completed and ready for factory inspection and testing: a. Indicate the desired dates for inspection and testing. b. Schedule the FAT after approval of the FAT procedures submittal: 1) Submit a copy of the test procedures including all forms at least 21 days before any scheduled test date. 2) Notify the Engineer of the scheduled tests a minimum of 15 days before the date of the test. 1.10 WARRANTY A. Warrant the Electrical Work as specified in Document 00_72_00: 1. Provide additional warranty as specified in the individual Electrical Specifications. 1.11 SYSTEM START-UP A. Replace or modify equipment, software, and materials that do not achieve design requirements after installation in order to attain compliance with the design requirements: 1. Following replacement or modification, retest the system and perform additional testing to place the complete system in satisfactory operation and obtain compliance acceptance from the Engineer. 1.12 MAINTENANCE A. Before Substantial Completion, perform all maintenance activities required by any sections of the Specifications including any calibrations, final adjustments, component replacements or other routine service required before placing equipment or systems in service. B. Furnish all spare parts as required by other sections of the Specifications. Page 126 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 PART 2 PRODUCTS 2.01 MANUFACTURERS A. Provide similar items of same manufacturer throughout the electrical and instrumentation portion of the Project. B. Allowable manufacturers are specified in individual Electrical Specifications. 2.02 MATERIALS A. Furnish all materials under this Contract that are new, free from defects, and standard products produced by manufacturers regularly engaged in the production of these products and that bear all approvals and labels as required by the Specifications. B. Stainless steel: 1. Where stainless steel is indicated or used for any portion of the Electrical Work, provide a non-magnetic, corrosion-resistant alloy, ANSI Type 316, satin finish. 2. Provide exposed screws of the same alloys. 3. Provide finished material free of any burrs or sharp edges. 4. Use only stainless steel hardware, when chemically compatible, in all areas that are or could be in contact with corrosive chemicals. 5. Use stainless steel hardware, when chemically compatible, in all chemical areas or areas requiring NEMA Type 4X construction. 6. Do not use stainless steel in any area containing chlorine, gas or solution, chlorine products or ferric chloride. 2.03 SOURCE QUALITY CONTROL A. Provide all equipment that is new, free from defects, and standard products produced by manufacturers regularly engaged in the production of these products. PART 3 EXECUTION 3.01 EXAMINATION A. Review the site conditions and examine all shop drawings for the various items of equipment in order to determine exact routing and final terminations for all wiring and cables. 3.02 INSTALLATION A. Equipment locations shown on Electrical Drawings may change due to variations in equipment size or minor changes made by others during construction: 1. Verify all dimensions indicated on the Drawings: a. Actual field conditions govern all final installed locations, distances, and levels. 2. Review all Contract Documents and approved equipment shop drawings and coordinate Work as necessary to adjust to all conditions that arise due to such changes. Page 127 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 3. Make minor changes in location of equipment before rough in, as directed by the Owner or Engineer. 4. Provide a complete electrical system: a. Install all extra conduits, cables, and interfaces as may be necessary to provide a complete and operating electrical system. B. Labeling: 1. Provide all nameplates and labels in accordance with Owner standards. C. Equipment tie-downs: 1. Anchor all instruments, control panels, and equipment by methods that comply with seismic and wind bracing criteria, which apply to the Site. 2. All control panels, VCPs, LCPs, RTUs, PCMs, etc., must be permanently mounted and tied down to structures in accordance with the Project seismic criteria. 3.03 COMMISSIONING A. As specified in Section 01_75_17. B. Owner training: 1. As specified in Section 01_75_17 and in this Section. 3.04 FIELD QUALITY CONTROL A. Inspection: 1. Allow for inspection of electrical system installation. 2. Provide any assistance necessary to support inspection activities. 3. Engineer inspections may include, but are not limited to, the following: a. Inspect equipment and materials for physical damage. b. Inspect installation for compliance with the Drawings and Specifications. c. Inspect installation for obstructions and adequate clearances around equipment. d. Inspect equipment installation for proper leveling, alignment, anchorage, and assembly. B. Field acceptance testing (Functional Testing): 1. Notify the Engineer when the Electrical Work is ready for field acceptance testing. 2. Perform the field acceptance tests as specified in Section 26_08_50. 3. Record results of the required tests along with the date of test: a. Use conduit identification numbers to indicate portion of circuit tested. END OF SECTION Page 128 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 129 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 26_12_20 LIQUID FILLED PAD MOUNTED TRANSFORMERS PART 1 GENERAL 1.01 SUMMARY A. Section includes: 1. Medium voltage, outdoor, liquid-filled pad mounted transformers. A. Related sections: 1. Section 01_33_00 - Submittal Procedures. 2. Section 01_75_17 - Commissioning. 3. Section 26_05_00 - Common Work Results for Electrical. 1.02 REFERENCES A. General: 1. As specified in Section 26_05_00. B. American National Standards Institute (ANSI). C. Institute of Electrical and Electronic Engineers (IEEE): 1. C57.12.00 - Standard General Requirements for Liquid-Immersed Distribution, Power and Regulating Transformers. 2. C57.12.26 - Pad-Mounted, Compartmental-Type, Self-Cooled, Three-Phase Distribution Transformers. 3. C57.12.28 - Standard for Pad-Mounted Equipment-Enclosure Integrity. 4. C57.12.70 - Standard Terminal Markings and Connections for Distribution and Power Transformers. 5. C57.12.80 - Terminology for Power and Distribution Transformers. 6. C57.12.90 - Standard Test Code for Liquid-Immersed Distribution, Power and Regulating Transformers. 7. C57.91 - Guide for Loading Mineral-Oil-Immersed Power Transformers up to and including 100 MVA with 65 degrees or 55 degrees Average Winding Rise. 8. C57.93 - Guide for Installation of Liquid-immersed Power Transformers. 9. C57.98 - Guide for Transformer Impulse Tests. 10. C57.106 - Guide for Acceptance and Maintenance of Insulating Oil in Equipment. D. National Electrical Manufacturers Association (NEMA): 1. TR-1 - Transformers, Regulators, and Reactors. E. U.S. Department of Energy (DOE): 1. 10 CFR Part 431 - Energy Efficiency Program for Certain Commercial and Industrial Equipment. 1.03 DEFINITIONS A. As specified in Section 26_05_00. Page 130 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 1.04 SYSTEM DESCRIPTION A. Outdoor oil-filled, pad mounted transformers for operation on a 60 Hertz system with voltage and kilovolt-ampere ratings as indicated on the Drawings: 1. Suitable for continuous operation at full load at the Project location and elevation after applying any derating factors. 2. Pad mounted transformers shall be compartmental type, designed for outdoor installation on a concrete pad. 3. Transformer core and insulation designed to operate for step-up and step- down operation. 1.05 SUBMITTALS A. Furnish submittals as specified in Sections 01_33_00 and 26_05_00. B. Product data: 1. Complete installation instructions. 2. Complete storage and handling instructions. 3. Kilovolt-ampere rating, including derating calculations. 4. Primary/secondary connections. 5. Primary voltage and available taps. 6. Secondary voltage. 7. BIL rating. 8. Temperature rise. 9. Lightning arrester data. 10. %Z, %X, %R, X/R. 11. Efficiency. 12. Gross weight. 13. Torque values for all bolted connections for secondary cable connections. 14. Manufacturer’s suggested hi-potential test procedures and test levels for field- testing: a. Initial field test. b. Subsequent maintenance tests. 15. Certification from the manufacturer stating the transformer design complies with ANSI C57. 16. Type of oil. 17. Gallons of oil. 18. Weight of oil. 19. Complete MSDS sheets. C. Shop drawings: 1. Complete detailed, dimensioned drawings showing the equipment being furnished, with all pertinent information, including the following: a. Dimensions and locations of conduit entrance windows. 2. Complete nameplate schedule, except impedance. Page 131 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 D. Installation instructions: 1. Detail the complete installation of the equipment including rigging, moving, and setting into place. 2. For equipment installed in structures designated as seismic design category A or B: a. Provide manufacturer’s installation instructions and anchoring details for connecting equipment to supports and structures. E. Operation and maintenance manuals: 1. Complete as-built dimensioned and scaled drawings for transformer. 2. Recommended periodic maintenance requirements. 3. Maintenance instructions including schedules, parts identification, troubleshooting, assembly instructions, parts list, and predicted life of parts subject to wear and deterioration. 4. Recommended field test levels and procedures before installation and for maintenance purposes after being placed in service. 5. Periodic and preventative maintenance torque values for all bolts. 6. Copies of factory test reports. F. Test reports: 1. Certified copies of test reports from factory tests. G. Record documents. 1.06 QUALITY ASSURANCE A. As specified in Section 26_05_00. B. Manufacturer qualifications: 1. Manufacturer shall be in the business of regularly manufacturing the specified transformers for minimum 10 years with satisfactory performance record. 1.07 DELIVERY, STORAGE, AND HANDLING A. As specified in Section 26_05_00. B. Ship transformers to the job site on a dedicated air ride vehicle that will allow the Contractor to utilize onsite off-loading equipment: 1. Each transformer shall be shipped with a global positioning system (GPS) unit to record the shipping route. 2. Provide monitoring of the acceleration the transformer experiences during shipment: a. The GPS unit can record the acceleration. b. Utilize a G-force gauge that indicates that the acceleration has exceeded allowed values. 3. Transformers that experience vertical accelerations greater than 3 G or horizontal accelerations greater than 5 G shall not be accepted. C. Furnish temporary equipment heaters within the transformer to prevent condensation from forming. Page 132 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 1.08 PROJECT OR SITE CONDITIONS A. As specified in Section 26_05_00. 1.09 SEQUENCING A. Make all necessary field measurements to verify the equipment will fit in the allocated space in full compliance with the minimum clearances required by the NEC and local codes. B. Conduct factory acceptance test and submit certified test results for Engineer’s review. C. Ship equipment to Project Site afer successful completsion of factory acceptance test. D. Assemble equipment in the field. E. Conduct field acceptance test and submit certified test results for Engineer’s review. F. Submit manufacturer’s certification that equipment has been proplerly installed and is fully functional for Engineer’s review. G. Set taps. H. Commissioning as specified in Section 01_75_17. 1.10 SCHEDULING (NOT USED) 1.11 WARRANTY A. As specified in Section 26_05_00. 1.12 SYSTEM START-UP A. As specified in Section 26_05_00. B. Provide the services of a manufacturer's authorized representative: 1. Inspect installation before start-up. 2. Witness energization. 1.13 OWNER’S INSTRUCTIONS (NOT USED) 1.14 MAINTENANCE (NOT USED) PART 2 PRODUCTS 2.01 MANUFACTURERS A. One of the following or equal: 1. Asea Brown Boveri – ABB. 2. General Electric GE. Page 133 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 3. Cooper Power Systems. 4. Schneider Electric/Square D Company. 2.02 EXISTING PRODUCTS (NOT USED) 2.03 MATERIALS A. Windings: 1. Primary and secondary windings shall be high conductivity copper. 2. Designed for step-down operation. B. Insulating fluid: 1. Envirotemp FR3. 2. Insulating fluid shall meet or exceed the requirements of the appropriate ANSI and ASTM fluid standards. 2.04 MANUFACTURED UNITS (NOT USED) 2.05 EQUIPMENT A. The transformer and associated terminal compartments designed and constructed to be tamper-resistant: 1. No externally removable screws, bolts, or other devices. B. Ratings: 1. 3-phase, 60 Hertz. 2. Self-cooled. 3. 65-degree Celsius rise. 4. Primary voltage as indicated on the Drawings. 5. Primary connection as indicated on the Drawings. 6. Secondary voltage as indicated on the Drawings. 7. Secondary connection as indicated on the Drawings. 8. Kilovolt-ampere rating as indicated on the Drawings. 9. Basic impulse insulation level (BIL): a. 1.2 kV Class: 30 kV. b. 2.5 kV Class: 45 kV. c. 5.0 kV Class: 75 kV. d. 8.7 kV Class: 75 kV. e. 15 kV Class: 95 kV. 10. Sound levels: a. In accordance with NEMA TR1. b. Measurement procedure in accordance with ANSI C57.12.90. 11. Efficiency: a. Transformers 2,500 kVA and less shall have an efficiency rating in accordance with DOE 10 CFR Part 431. 12. Short-circuit capacity: a. Mechanical short-circuit capability in accordance with ANSI C57.12.90. 13. Thermal short-circuit capability in accordance with ANSI C57.12.00. Page 134 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 2.06 COMPONENTS A. Core and coil: 1. Manufactured from burr-free, grain-oriented silicon steel laminations and stacked to eliminate gaps in the corner joints. 2. Insulated with B-stage, epoxy coated, diamond pattern, insulating paper, thermally cured under pressure to ensure proper bonding of conductor and paper. 3. Clamped and braced to resist distortion caused by short-circuit stresses within ratings or by shipping and handling and to prevent the shifting of core laminations. 4. Vacuum processed to ensure maximum penetration of insulating fluid into the coil insulation system: a. Energize the windings under vacuum to heat the coils and drive out moisture. b. While under a vacuum and the coils are heated, fill the tank with preheated, filtered and degassed insulating fluid. B. Tank: 1. Conforming to the enclosure integrity requirements of ANSI C57.12.28. 2. Equipped with extra-heavy duty, welded-in-place lifting lugs and jacking pads. a. Provide adequate cross-bracing of the base to allow skidding or rolling in any direction. 3. Capable of withstanding a pressure of 7 pounds per square inch gauge without permanent distortion, and 15 pounds per square inch gauge without rupturing. 4. Provide a pressure relief valve as a means to relieve pressure in excess of pressure resulting from normal operation: a. Cracking pressure: 10 pounds per square inch gauge within 2 psig. b. Resealing pressure: 6 pounds per square inch gauge minimum. c. Zero leakage from reseal pressure to 8 pounds per square inch gauge. d. Flow at 15 pounds per square inch gauge: 35 scfm minimum. C. Terminal compartments: 1. Conforming to the enclosure integrity requirements of ANSI C57.12.28. 2. Full-height, air filled primary and secondary terminal compartments with hinged doors shall be located side-by-side separated by a steel barrier, with the primary compartment on the left, complete with tamper resistant hardware. 3. Hinges and pins to be passivated Type 304 stainless steel or equivalent corrosion-resistant metal. 4. Doors and compartment hood shall be removable: a. Removable doorsill on compartments shall be provided to permit rolling or skidding of unit into place over conduit stubs in foundations. 5. The doors in both the high voltage section and the low voltage section shall be able to be latched in the open position. 6. The entire terminal compartment for the transformer shall be bolted to the transformer so that the terminal compartment may be unbolted from the transformer and the transformer removed without disturbing conduits that enter the compartment from the side or top. 7. Minimum of 30 inches deep. Page 135 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 8. Secondary compartment: a. The secondary compartment shall enclose the low voltage bushings and provide for incoming cable from below the compartment. b. This compartment shall also house: 1) Liquid level indicator. 2) Drain valve with sampling device. 3) Dial type thermometer. 4) Pressure relief valve. 5) Vacuum pressure gauge. c. Door to low voltage section shall have a 3-point latching mechanism with pad-locking provision. 9. Primary compartment: a. The primary line compartment shall enclose the high voltage bushings and provide for incoming cables from below the compartment. 1) Coordinate primary bushing size with incoming cables size as indicated on the Drawings. b. This compartment shall also house: 1) Dead front lightning arresters. 2) No-load tap changer. 3) Parking stands for 6 elbows. c. The primary compartment shall be accessible only after the door for the secondary compartment has been opened. The door shall be held closed by a captive bolt; access to this bolt shall be provided only when the door to the low voltage section is opened. 10. Primary terminals: a. Dead front construction, in accordance with ANSI C57.12.26, utilizing high voltage elbows for connections to primary cable and lightning arresters. b. Terminal arrangement with 6-bushing wells: 1) 3 for terminating primary power cables. 2) 3 for connecting lightning arresters. c. Supporting structure within cabinet to support cables and eliminate mechanical stress on insulators. d. Where indicated on the Drawings, provide the option for bayonet fuses on the primary. 11. Secondary terminals: a. Four low voltage spade bushings with 2 holes for each cable, in accordance with ANSI C57.12.26. b. Extend low voltage bushings as necessary to accommodate the cable arrangement indicated on the Drawings or indicated on the conduit schedule: 1) Extension via a fully rated, tin-plated, copper bus system braced to withstand the available fault current. c. Neutral brought out through an insulated bushing and externally grounded to the tank with a removable ground strap. d. Supporting structure within cabinet to support cables and eliminate mechanical stress on insulators. D. De-energized tap changer: 1. Furnish with full capacity high-voltage taps: a. Two 2-1/2 percent taps above and below rated voltage. 2. Labeled to indicate that the transformer must be de-energized before operating the tap changer as required by IEEE C57.12.10. Page 136 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 3. Externally operated no-load tap changer switch with snap action switch and lever handle. 4. Padlocking provision in each tap position. 5. Position indication. 2.07 ACCESSORIES A. Lightning arresters: 1. High voltage dead front design for elbow connection. 2. Metal oxide varistor arresters. 3. Distribution class arresters. 4. Rating as indicated on the Drawings and/or consistent with the distribution voltage. B. Tank ground pads: 1. Two stainless steel pads, welded to the tank wall, with unpainted surfaces: a. One pad in primary compartment. b. One pad in secondary compartment: 1) If additional load ground connections are required, a tin-plated, copper equipment ground bus shall be bolted to the pad. C. Dial-type thermometer: 1. Direct stem mounted in a closed well so that the thermometer can be removed without breaking the tank seal: a. The well shall be threaded into a fitting that is welded to the transformer tank wall. 2. The thermometer shall have a slave hand which is moved by the indicating hand to indicate maximum oil temperature. The slave hand shall be externally resettable. D. Sampling device: 1. Allow for sampling of the transformer insulating fluid. 2. Threaded into a fitting that is welded to the transformer tank wall. E. Liquid level gauge: 1. Dial-type liquid level gauge. F. Vacuum pressure gauge: 1. 10 pounds per square inch gauge vacuum to plus 10 pounds per square inch gauge scale: G. Pressure relief device: 1. Located in the air space in the transformer tank to provide a method of relieving internal tank pressure. 2. Self-relieving. 3. Indicating. 4. Operating pressure: 10 within 2 pounds per square inch gauge. Page 137 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 H. Nameplates: 1. Provide nameplate as specified in Section 26_05_53 and the following: a. Provide complete nameplates identifying equipment, caution, voltage, etc. b. Provide complete nameplates for both inside and outside of the transformer terminal compartments. c. Provide diagrammatic nameplate. I. Bolted 8-inch (minimum) diameter round handhold on cover. J. Lifting lugs at each corner of tank for lifting complete transformer. K. Jacking facilities at each corner of base for jacking the complete transformer. L. Base designed for rolling or skidding in any direction. 2.08 MIXES (NOT USED) 2.09 FABRICATION A. Tanks: 1. Construction: Sealed tank construction with welded cover. Permanently locate an inorganic gasket between the cover and the tank flange during the welding of the transformer cover to prevent the entrance of weld spatter into the tank. 2. Large handhole with bolted cover and protected with a weather cover. 3. 4 lifting hooks. 4. Jacking pads. 5. Fluid sample valve. 6. Designed for 7 pounds per square inch gauge without permanent distortion; 12 pounds per square inch gauge when silicone oil insulating fluid is specified. 2.10 FINISHES A. In accordance with ANSI C57.12.28 including the following performance requirements: 1. Salt spray test. 2. Crosshatch adhesion test. 3. Humidity test. 4. Impact test. 5. Oil resistance test. 6. Ultraviolet accelerated weathering test. 7. Abrasion resistance - taber abraser. B. Procedure: 1. Clean with an alkaline cleaning agent to remove grease and oil. 2. Chemically bond iron phosphate coating to metal surface to assure coating adhesion and retard corrosion. 3. Prime metal surface with an electrodeposited powder epoxy to provide a barrier against moisture, salt, and corrosives. 4. Coat with an electrostatically applied, oven-cured polyester powder coat to enhance abrasion and impact resistance. 5. Topcoat: Liquid polyurethane coating to seal and add ultraviolet protection. a. Color: Munsell Green 7GY. Page 138 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 2.11 SOURCE QUALITY CONTROL (NOT USED) PART 3 EXECUTION 3.01 EXAMINATION (NOT USED) 3.02 PREPARATION (NOT USED) 3.03 INSTALLATION A. As specified in Section 26_05_00. B. Install the equipment in accordance with the accepted installation instructions and anchorage details to meet the seismic and wind load requirements at the Project site. C. General: 1. Furnish concrete pad and all lugs, bolts, anchors, sealants, and other accessories needed to complete the installation of the transformer. 2. Assemble and install the transformer in the location and layout indicated on the Drawings. 3. Perform Work in accordance with manufacturer’s instructions and shop drawings. 4. Raise the tank above the pad to protect the bottom finish during installation and to minimize corrosion due to moisture accumulation. 5. Furnish components and equipment as required to complete the installation. 6. Replace any hardware lost or damaged during installation or handling. 7. Position the transformer so all required working space and clearance requirements of the National Electrical Code and the local building authorities are met. 3.04 ERECTION, INSTALLATION, APPLICATION, CONSTRUCTION (NOT USED) 3.05 REPAIR/RESTORATION (NOT USED) 3.06 RE-INSTALLATION (NOT USED) 3.07 COMMISSIONING A. As specified in Section 01_75_17. B. Perform the following factory tests as required by IEEE C57.12.00 and in accordance with IEEE C57.12.90: 1. No-load (85 degrees Celsius) losses at rated current. (Maximum allowable no load losses: 10 percent.) 2. Total (85 degrees Celsius) losses at rated current. (Maximum allowable total losses: 6 percent.) 3. Percent impedance (85 degrees Celsius) at rated current. 4. Excitation current (100 percent voltage) test. 5. Winding resistance measurement tests. Page 139 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 6. Turns ratio tests using all tap settings. 7. Polarity and phase relation tests. 8. Temperature test. C. Verification of performance: 1. Submit manufacturer's certified test results before shipping the transformer. 3.08 FIELD QUALITY CONTROL A. As specified in Section 26_08_50. B. Any and all other Work required to make the transformer ready for testing and energization. 3.09 ADJUSTING A. Set the transformer taps as required to obtain nominal output voltage on the secondary terminals. 3.10 CLEANING A. As specified in Section 26_05_00. 3.11 PROTECTION A. As specified in Section 26_05_00. 3.12 SCHEDULES (NOT USED) END OF SECTION Page 140 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 141 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 26_24_14 GROUP-MOUNTED CIRCUIT BREAKER SWITCHBOARDS PART 1 GENERAL 1.01 SUMMARY A. Section includes: 1. Free standing, dead-front type metal-enclosed distribution, low voltage switchboards, utilizing group mounted circuit protective devices. B. Related sections: 1. Section 01_33_00 - Submittal Procedures. 2. Section 01_75_17 - Commissioning. 3. Section 26_05_00 - Common Work Results for Electrical. 4. Section 26_28_01 - Low Voltage Molded Case Circuit Breakers. 1.02 REFERENCES A. As specified in Section 26_05_00. B. National Electrical Manufacturers' Association (NEMA): 1. PB-2 - Dead-front Distribution Switchboards. C. Underwriters' Laboratories, Inc. (UL): 1. 50 - Standard for Enclosures for Electrical Equipment. 2. 891 - Switchboards. 1.03 DEFINITIONS A. As specified in Section 26_05_00. 1.04 SYSTEM DESCRIPTION A. Factory assembled, wired, and tested switchboards, with major components being products of a single manufacturer, including but not limited to, circuit breakers, bus and enclosure with accessories and features specified in this Section and indicated on the Drawings. B. Description of sections: 1. Space for future devices: a. Where indicated on the Drawings, space for future devices shall include: 1) All necessary bus. 2) Device supports. 3) Device mounting equipment. 4) Device connections to bus work. 5) Wire troughs or raceway space. 6) Unused device space shall be covered with blank code gauge steel covers or doors. Page 142 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 1.05 SUBMITTALS A. Furnish submittals as specified in Sections 01_33_00 and 26_05_00. B. Product data: 1. Manufacturer of switchboard. 2. Manufacturer of all component parts of switchboard. 3. Weight of switchboard. 4. Dimensions: a. Height. b. Length. c. Width. 5. Nameplate schedule. 6. Bill of material. 7. Ratings: a. Voltage. b. Phase. c. Current. d. Interrupting rating (circuit breakers and fuses). e. Momentary current rating. 8. List of recommended spare parts. 9. Name and telephone number of manufacturer’s authorized parts and repair provider. 10. Furnish circuit breaker submittals as specified in: a. Section 26_28_01. C. Shop drawings: 1. Layout drawings: a. Complete, detailed, and scaled switchboard layout: 1) Front panel. 2) Sub-panels. 3) Interior panels. 4) Top and bottom conduit windows. D. Installation instructions: 1. Detail the complete installation of the equipment including rigging, moving, and setting into place. 2. For equipment installed in structures designated as seismic design category A or B: a. Provide manufacturer’s installation instructions and anchoring details for connecting equipment to supports and structures. E. Operating and maintenance manuals: 1. Submit operating instructions and a maintenance manual for the switchboard(s) furnished and/or installed under this Contract. 2. Maintenance manual: a. Furnish maintenance manuals with instructions covering all details pertaining to care and maintenance of all equipment as well as data identifying all parts. b. Manuals to include but are not limited to the following: 1) Adjustment and test instructions covering the steps involved in the initial test, adjustment, and start-up procedures. Page 143 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 F. Test forms and reports: 1. Manufacturer to furnish a certified report after the start-up: a. Report must state that the installation is complete and satisfactory, or list items requiring additional and a proposal for the corrective actions. G. Certification letters: 1. Provide a letter from the switchboard manufacturer that lists every paragraph, subparagraph etc. of this Section and states compliance or non-compliance with said paragraph. If non-compliance is indicated, provide an explanation for the deviation and alternative method to address the non-compliance. 1.06 QUALITY ASSURANCE A. As specified in Section 26_05_00. B. Sections and devices shall be UL listed and labeled. C. The manufacturer of this equipment shall have produced similar electrical equipment for a minimum period of 5 years. When requested by the Engineer, an acceptable list of installations with similar equipment shall be provided demonstrating compliance with this requirement. 1.07 DELIVERY STORAGE AND HANDLING A. As specified in Section 26_05_00. B. Ship the switchboard to the job site on a dedicated air ride vehicle that will allow the Contractor to utilize onsite off-loading equipment: 1. Energize space heaters in NEMA 3R switchboards. C. Furnish temporary equipment heaters within the switchboard to prevent condensation from forming. 1.08 PROJECT OR SITE CONDITIONS A. As specified in Section 26_05_00. 1.09 SEQUENCING A. Ship equipment to Project Site after successful completion of factory acceptance test. B. Assemble equipment in the field. C. Submit manufacturer’s certification that equipment has been properly installed and is fully functional for Engineer’s review. D. Conduct Owner’s training sessions. E. Commissioning as specified in Section 01_75_17. Page 144 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 1.10 SCHEDULING A. As specified in Section 26_05_00. 1.11 WARRANTY A. As specified in Section 26_05_00. 1.12 SYSTEM START-UP A. As specified in Section 26_05_00. 1.13 OWNER’S INSTRUCTIONS (NOT USED) 1.14 MAINTENANCE (NOT USED) PART 2 PRODUCTS 2.01 MANUFACTURERS A. One of the following or equal: 1. Eaton/Cutler-Hammer, "Pow-R-Line C.” 2. General Electric Company, "Spectra Series.” 3. Schneider Electric/Square D. “Power-Style QED.” B. Circuit breakers: Same manufacturer as the switchboard. 2.02 EXISTING PRODUCTS (NOT USED) 2.03 MATERIALS (NOT USED) 2.04 MANUFACTURED UNITS (NOT USED) 2.05 EQUIPMENT A. Switchboard: 1. Furnish low voltage Class 1 switchboards as specified and indicated on the Drawings. 2. Provide complete and functional switchboards with required controls. 3. Furnish and install devices or accessories not described in this Section but necessary for the proper installation and operation of the equipment. B. Voltage ratings: 1. Voltage level and configuration: As indicated on the Drawings. 2. Frequency: 60 hertz. 3. Solidly grounded system insulation level: a. Twice the rated voltage plus 1,000 volts. C. Bus: 1. General: a. Tin-plated copper. b. Bus cross-section in accordance with UL heat rise requirements. Page 145 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 c. Current density of 1,000 amperes per square inch. d. Mounted on supports of high-impact, non-tracking insulators. e. Phase A-B-C bus arrangement: 1) Top-to-bottom, left-to-right, front-to-back throughout the switchboard. f. Symmetrical short circuit current bracing of as indicated on the Drawings. g. Continuous current rating as indicated on the Drawings. 2. Horizontal bus: a. Provisions for future connections to additional switchboard sections. 3. Ground bus: a. Sized per UL 891. D. Enclosure: 1. General: a. Self-supporting structures bolted together to form the required line-up. b. All sections rear aligned. c. Dead-front. d. Conduit entry: 1) Open-bottom. 2) Removable top cover. 2. Frame: a. Die-formed 12 gauge steel. 3. Covers: a. Bolt-on. b. Code gauge steel. c. Removable front covers. 1) Held in place by captive screws. 4. Rating: a. NEMA Type 3R: 1) Sloped roof. 2) Filtered roof vents. 3) Space heaters to prevent condensation. 4) Doors: a) Front and rear. b) Wind stop on each door. c) 3-point catch with provision for padlock. d) Front to rear full depth lifting beams. 5) Gasketed. 6) Non walk-in construction. 2.06 COMPONENTS A. Circuit breakers: 1. General: a. Molded case circuit breakers as specified in Section 26_28_01. b. Frame, trip, and short circuit ratings as indicated on the Drawings. B. Wiring: 1. Provide all necessary internal wiring, fuse blocks, and terminal blocks as required. 2. Number all wires at each end and indicate wire numbers on shop drawings. 3. Type SIS switchboard wire with at least 26 strands. Page 146 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 4. Minimum wire size: a. No. 14 for control circuits. b. No. 12 for potential and current transformer circuits. 2.07 ACCESSORIES A. Nameplates: 1. Plastic engraved nameplates to be provided by Contractor in accordance with Owner standards. Nameplates shall identify: a. Switchboard units. b. Door mounted components. c. Interior mounted devices. 2. Manufacturers labels: a. Each vertical section shall have a label identifying: 1) Serial number. 2) Shop order number. 3) Bus rating. 4) Vertical section reference number. 5) Date of manufacture. B. Warning signs: 1. Voltage: a. Provide a minimum of 2 warning signs on the front of the switchboard lineup and 2 on the back. b. Red laminated plastic engraved with white letters approximately 1/2 inch high. c. Signs shall read: 1) "WARNING-HIGH VOLTAGE-KEEP OUT". 2. Arc flash: a. Provide one warning sign for each switchboard compartment. b. Signs shall have read a minimum of: 1) “DANGER ELECTRIC ARC FLASH HAZARD.” 2) Signs shall meet the requirements of NFPA 70E and NEC Article 110.16. C. Lugs: 1. For all external connections of No. 6 AWG or larger. 2. UL listed for copper or aluminum conductors. 3. Rated for 75-degree Celsius conductors. 4. Lugs shall be of the compression type in design requiring a hydraulic press and die for installation. 2.08 MIXES (NOT USED) 2.09 FABRICATION (NOT USED) 2.10 FINISHES A. Chemically clean all steel surfaces before painting. B. Exterior color manufacturer’s standard gray over phosphate-type rust inhibitor. Page 147 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 2.11 SOURCE QUALITY CONTROL (NOT USED) PART 3 EXECUTION 3.01 EXAMINATION (NOT USED) 3.02 PREPARATION (NOT USED) 3.03 INSTALLATION A. As specified in Section 26_05_00. B. Install the equipment in accordance with the accepted installation instructions and anchorage details to meet the seismic and wind load requirements at the Project site. C. General: 1. Furnish all cables, conduit, lugs, bolts, expansion anchors, sealants, and other accessories needed to complete the installation of the switchboard. 2. Assemble and install the switchboard in the location and layout indicated on the Drawings. 3. Perform work in accordance with manufacturer’s instructions and shop drawings. 4. Furnish components and equipment as required to complete the installation. 5. Replace any hardware lost or damaged during the installation or handling to provide a complete installation. 3.04 ERECTION, INSTALLATION, APPLICATION, CONSTRUCTION (NOT USED) 3.05 REPAIR/RESTORATION (NOT USED) 3.06 REINSTALLATION (NOT USED) 3.07 COMMISSIONING A. As specified in Section 01_75_17. B. Factory testing: 1. Perform standard factory tests on the panelboards: 2. Test in accordance with the latest version of NEMA and UL standards. 3.08 FIELD QUALITY CONTROL A. As specified in Section 26_05_00. 3.09 ADJUSTING A. Make all adjustments as necessary and recommended by the manufacturer, Engineer, or testing firm. Page 148 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 3.10 CLEANING A. As specified in Section 26_05_00. 3.11 PROTECTION A. As specified in Section 26_05_00. 3.12 SCHEDULES (NOT USED) END OF SECTION Page 149 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 26_28_01 LOW VOLTAGE MOLDED CASE CIRCUIT BREAKERS PART 1 GENERAL 1.01 SUMMARY A. Section includes: 1. Low voltage molded case circuit breakers. B. Related sections: 1. Section 01_33_00 - Submittal Procedures. 2. Section 01_75_17 - Commissioning. 3. Section 26_05_00 - Common Work Results for Electrical. 1.02 REFERENCES A. As specified in Section 26_05_00. B. National Electrical Manufacturers Association (NEMA): 1. AB 3. - Molded Case Circuit Breakers and Their Application. C. Underwriter’s Laboratories (UL): 1. 489 - Molded-Case Circuit Breakers, Molded-Case Switches, and Circuit- Breaker Enclosures. 2. 943 - Ground Fault Circuit Interrupters. 1.03 DEFINITIONS A. As specified in Section 26_05_00. B. In accordance with UL 489. 1.04 SYSTEM DESCRIPTION A. Molded case thermal magnetic or motor circuit protector type circuit breakers as indicated on the Drawings and connected to form a completed system. 1.05 SUBMITTALS A. Furnish submittals as specified in Sections 01_33_00 and 26_05_00. B. Product data: 1. Catalog cut sheets. 2. Manufacturer’s time-current curves for all molded case circuit breakers furnished. Page 150 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 1.06 QUALITY ASSURANCE A. As specified in Section 26_05_00. B. Low voltage molded case circuit breakers shall be UL listed and labeled. 1.07 DELIVERY, STORAGE AND HANDLING A. As specified in Section 26_05_00. 1.08 PROJECT OR SITE CONDITIONS A. As specified in Section 26_05_00. 1.09 SEQUENCING (NOT USED) 1.10 SCHEDULING (NOT USED) 1.11 WARRANTY A. As specified in Section 26_05_00. 1.12 SYSTEM START-UP A. As specified in Section 26_05_00. 1.13 OWNER’S INSTRUCTIONS (NOT USED) 1.14 MAINTENANCE (NOT USED) PART 2 PRODUCTS 2.01 MANUFACTURERS A. One of the following or equal: 1. Eaton/Cutler-Hammer. 2. General Electric Company. 3. Schneider Electric/Square D Company. 2.02 EXISTING PRODUCTS (NOT USED) 2.03 MATERIALS (NOT USED) 2.04 MANUFACTURED UNITS A. General: 1. Conforming to UL 489. 2. Operating mechanism: a. Quick-make, quick-break, non-welding silver alloy contacts. b. Common Trip, Open and Close for multi-pole breakers such that all poles open and close simultaneously. c. Mechanically trip free from the handle. Page 151 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 d. Trip indicating handle - automatically assumes a position midway between the manual ON and OFF positions to clearly indicate the circuit breaker has tripped. e. Lockable in the "OFF" position. 3. Arc extinction: a. In arc chutes. 4. Voltage and current ratings: a. Minimum ratings as indicated on the Drawings. b. Minimum frame size 100A. 5. Interrupting ratings: a. Minimum ratings as indicated on the Drawings. b. Modify as required to meet requirements of the short circuit fault analysis. c. Not less than the rating of the assembly (panelboard, switchboard, motor control center, etc.) B. Motor circuit protectors: 1. Instantaneous only circuit breaker as part of a listed combination motor controller. 2. Each pole continuously adjustable in a linear scale with ‘LO’ and ‘HI’ settings factory calibrated. 2.05 EQUIPMENT (NOT USED) 2.06 COMPONENTS A. Terminals: 1. Line and load terminals suitable for the conductor type, size, and number of conductors in accordance with UL 489. B. Case: 1. Molded polyester glass reinforced. 2. Ratings clearly marked. C. Trip units: 1. Provide thermal magnetic or solid-state trip units as indicated on the Drawings. 2. Thermal magnetic: a. Instantaneous short circuit protection. b. Inverse time delay overload. c. Ambient or enclosure compensated by means of a bimetallic element. 3. Solid state: a. With the following settings as indicated on the Drawings. 1) Adjustable long time current setting. 2) Adjustable long time delay. 3) Adjustable short time pickup. 4) Adjustable short time delay. 5) Adjustable instantaneous pickup. 6) Adjustable ground fault pickup as indicated on the Drawings. 7) Adjustable ground fault delay as indicated on the Drawings. D. Provide ground fault trip devices as indicated on the Drawings. Page 152 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 E. Molded case circuit breakers for use in panelboards: 1. Bolt-on type. a. Plug-in type breakers are not acceptable. 2. Ground fault trip devices as indicated on the Drawings. 2.07 ACCESSORIES 2.08 MIXES (NOT USED) 2.09 FABRICATION (NOT USED) 2.10 FINISHES (NOT USED) 2.11 SOURCE QUALITY CONTROL A. Test breakers in accordance with: 1. UL 489. 2. Manufacturer’s standard testing procedures. PART 3 EXECUTION 3.01 EXAMINATION (NOT USED) 3.02 PREPARATION (NOT USED) 3.03 INSTALLATION A. Install breakers to correspond to the accepted shop drawings. 3.04 ERECTION, INSTALLATION, APPLICATION, CONSTRUCTION (NOT USED) 3.05 REPAIR/RESTORATION (NOT USED) 3.06 RE-INSTALLATION (NOT USED) 3.07 COMMISSIONING A. As specified in Section 01_75_17. 3.08 FIELD QUALITY CONTROL A. As specified in Section 26_05_00. 3.09 ADJUSTING A. Adjust trip settings in accordance with Protective Device Coordination Study as accepted by the Engineer and in accordance with manufacturer’s recommendations. B. Adjust motor circuit protectors in accordance with NEC and the manufacturer’s recommendation based on the nameplate values of the installed motor. Page 153 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 3.10 CLEANING (NOT USED) 3.11 PROTECTION A. As specified in Section 26_05_00. 3.12 SCHEDULES (NOT USED) END OF SECTION Page 154 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Page 155 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 SECTION 26_43_14 SURGE PROTECTIVE DEVICES PART 1 GENERAL 1.01 SUMMARY A. Section includes: 1. High-energy surge protective devices. B. Related sections: 1. Section 01_33_00 - Submittal Procedures. 2. Section 01_75_17 - Commissioning. 3. Section 26_05_00 - Common Work Results for Electrical. 1.02 REFERENCES A. As specified in Section 26_05_00. B. Institute of Electrical and Electronics Engineers (IEEE): 1. C62.41 - Recommended Practice on Surge Voltages in Low Voltage AC Power Circuits. 2. C62.45 - Guide on Surge Testing for Equipment Connected to Low-Voltage (1000 V and Less) AC Power Circuits. 3. C62.62 - Standard Test Specifications for Surge Protective Devices for Low Voltage AC Power Circuits. C. Underwriters Laboratory: 1. 1449, 3rd Edition, Standard for Surge Protective Devices. 1.03 DEFINITIONS A. As specified in Section 26_05_00. B. Specific definitions: 1. SPD: Surge protective device. 2. SAD: Silicon avalanche diode. 3. MOV: Metal oxide varistor. 4. MCOV: Maximum continuous operating voltage. 5. In: Nominal discharge current. 6. VPR: Voltage protection rating. 7. SCCR: Short circuit current rating. 1.04 SYSTEM DESCRIPTION A. Surge protective devices as an integral component of the electrical equipment or externally mounted as indicated on the Drawings. Page 156 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 1.05 SUBMITTALS A. Furnish submittals as specified in Sections 01_33_00 and 26_05_00. B. Product data: 1. Furnish complete product data confirming detailed compliance or exception statements to all provisions of this Section. 2. Manufacturer’s catalog cut sheets indicating: a. Manufacturer and model numbers. b. Ratings of each SPD including but not limited to: 1) Short circuit current rating. 2) Nominal discharge current. 3) Maximum continuous operating voltage. 4) Voltage protection rating. 5) System voltage. 6) System frequency. 7) Surge current capacity. 3. Submit independent test data from a nationally recognized testing laboratory verifying the following: a. Overcurrent protection. b. UL 1449. C. Shop drawings: 1. Provide electrical and mechanical drawings by the manufacturer that detail: a. Unit dimensions. b. Weights. c. Components. d. Field connection locations. e. Mounting provisions. f. Connection details. g. Wiring diagram. D. Operation and maintenance manuals: 1. Provide the manufacturer’s manual with installation, start-up, spare parts lists, and operating instructions for the specified system. 1.06 QUALITY ASSURANCE A. As specified in Section 26_05_00. B. Provide SPD units that are designed, manufactured, tested and installed in compliance with the following codes and standards: 1. Institute of Electrical and Electronics Engineers (IEEE C62.41, C62.45, C62.62). 2. Federal Information Processing Standards Publication 94 (FIBS PUB 94). 3. National Electrical Manufacturer Association. 4. National Fire Protection Association (NFPA 20, 75 and 780). 5. National Electric Code (NFPA 70). 6. Underwriters Laboratories (UL 1449 3rd Edition and UL 1283). 7. International Electrotechnical Commission (IEC 801). Page 157 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 1.07 DELIVERY, STORAGE, AND HANDLING A. As specified in Section 26_05_00. 1.08 PROJECT OR SITE CONDITIONS A. As specified in Section 26_05_00. 1.09 SEQUENCING A. Coordinate with and provide SPD equipment to the electrical equipment manufacturer before final assembly and factory testing. 1.10 SCHEDULING (NOT USED) 1.11 WARRANTY A. As specified in Section 26_05_00. B. Extended warranty: 1. Furnish a manufacturer’s full 5-year parts and labor warranty from date of shipment against any part failure when installed in compliance with manufacturer's written instructions, UL listing requirements, and any applicable national, state, or local electrical codes. 2. Warranty shall include: a. Direct, factory trained employees must be available within 48 hours for assessment of the problem. b. A 24-hour toll-free 800-number for warranty support. 1.12 SYSTEM START-UP A. As specified in Section 26_05_00. 1.13 OWNER'S INSTRUCTIONS (NOT USED) 1.14 MAINTENANCE (NOT USED) PART 2 PRODUCTS 2.01 MANUFACTURERS A. One of the following or equal: 1. Liebert. 2. Eaton/Cutler-Hammer. 3. Schneider Electric/Square D. 4. General Electric. 2.02 EXISTING PRODUCTS (NOT USED) 2.03 MATERIALS (NOT USED) Page 158 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 2.04 MANUFACTURED UNITS A. Provide Type 1 or Type 2 SPD units as required for the locations indicated on the Drawings. B. Electrical requirements: 1. SPD ratings are to be consistent with the nominal system operating voltage, phase, and configuration as indicated on the Drawings. 2. MCOV: a. For the SPD and all components in the suppression path (including all MOVs, SADs, and selenium cells): Greater than 115 percent of the nominal system operating voltage. 3. Operating frequency: a. 47 to 63 hertz. 4. SCCR: a. 65 kAIC minimum, but not less than the equipment it is connected to as indicated on the Drawings. b. The SCCR shall be marked on the SPD in accordance with UL 1449 and the NEC. 5. Nominal discharge current In: a. 20 kA. 6. Maximum VPR: Modes 240/120 208Y/120 480Y/277 L-N, L-G, N-G 900 900 1,500 L-L 1,200 1,200 2000 7. Peak surge current: a. Service entrance locations: 1) 240 kA per phase minimum. 2) 120 kA per mode minimum. b. Branch locations: 1) 120 kA per phase, minimum. 2) 60 kA per mode minimum. C. Protection modes: 1. Provide SPD protection modes as follows: a. Line to Neutral (L-N) where applicable. b. Line to Ground (L-G). c. Neutral to Ground (N-G), where applicable. D. Environmental requirements: 1. Storage temperature: a. -40 degrees to +50 degrees Celsius. 2. Operating temperature: a. -0 degrees to +60 Celsius. 3. Relative humidity: a. 5 percent to 95 percent. 4. Audible noise: a. Less than 45 dBa at 5 feet (1.5 m). 5. Operating altitude: a. Zero to 12,000 feet above sea level. Page 159 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 E. Provide surge protective devices that are suitable for application in IEEE C62.41 Category A, B and C3 environments, as tested to IEEE C62.45. 2.05 EQUIPMENT (NOT USED) 2.06 COMPONENTS A. Enclosure: 1. Located in electrical equipment as indicated on the Drawings. B. Internal connections: 1. Provide low impedance copper plates for intra-unit connections: a. Attach surge modules using bolted connections to the plates for low impedance connections. 2. Size all connections, conductors, and terminals for the specified surge current capacity. C. Surge diversion modules: 1. MOV: a. Where multiple MOVs are used in parallel, utilize computer matched MOVs to within 1 volt variance and tested for manufacturer's defects. D. Overcurrent protection: 1. Individually fuse all components, including suppression, filtering, and monitoring components: a. Rated to allow maximum specified nominal discharge current capacity. b. Overcurrent protection that limits specified surge currents is not acceptable. E. Connections: 1. Provide terminals to accommodate wire sizes up to #2 AWG. 2.07 ACCESSORIES A. Unit status indicators: 1. Provide red and green solid-state indicators, with printed labels, on the front cover to redundantly indicate on-line unit status: a. The absence of the green light and the presence of the red light indicate that surge protection is reduced and service is needed to restore full operation. b. Indicates the status of protection on each mode or phase. B. Dry contacts for remote monitoring: 1. Electrically isolated Form C dry contacts (1 A/125 VAC) for remote monitoring of system integrity, and indication of under voltage, phase and/or power loss. C. Provide an audible alarm which activates under any fault condition. 1. Provide an alarm On/Off switch to silence the alarm. 2. A visible LED will confirm whether alarm is On or Disabled. 3. Locate both switches and the audible alarm on the unit’s front cover. 2.08 MIXES (NOT USED) 2.09 FABRICATION (NOT USED) Page 160 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 2.10 FINISHES (NOT USED) 2.11 SOURCE QUALITY CONTROL A. Permanently affix surge rating to the SPD. B. Perform manufacturer’s standard factory test. 1. Perform testing in accordance with UL 1449. PART 3 EXECUTION 3.01 EXAMINATION (NOT USED) 3.02 PREPARATION (NOT USED) 3.03 INSTALLATION A. As specified in Section 26_05_00. B. Follow the manufacturer's recommended installation practices and comply with all applicable codes. C. Special techniques: 1. Do not subject SPD to insulation resistance testing. 3.04 ERECTION, INSTALLATION, APPLICATION, CONSTRUCTION (NOT USED) 3.05 REPAIR/RESTORATION (NOT USED) 3.06 RE-INSTALLATION (NOT USED) 3.07 COMMISSIONING A. As specified in Section 01_75_17. 3.08 FIELD QUALITY CONTROL A. As specified in Section 26_08_50. 3.09 ADJUSTING (NOT USED) 3.10 CLEANING (NOT USED) 3.11 PROTECTION A. As specified in Section 26_05_00. 3.12 SCHEDULES (NOT USED) END OF SECTION Page 161 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 REV DATE BY DESCRIPTION DATE CHECKED DRAWN DESIGNED 10545B.10 JOB NO. DRAWING NO. SHEET NO. SCALES ACCORDINGLY VERIFY SCALES THIS SHEET, ADJUST IF NOT ONE INCH ON BAR IS ONE INCH ON ORIGINAL DRAWING 0 1" SEPTEMBER 2017 OF XX DRAKE WATER RECLAMATION FACILITY (DWRF) DRAKE WRF DEWATERING 1 2 3 4 5 6 7 8 9 10 11 12 13 A B C D E F 1 2 3 4 5 6 7 8 9 10 11 12 13 A B C D E F G G NOT FOR CONSTRUCTION ® SUBMITTAL INTERMEDIATE DESIGN Z=5.75% REFER DWG. ESD-EDD-2 13.2KV-480/277V 1000 KVA HVT1204 SWITCHGEAR "B" BUS CONTINUED PFC1204 SFB1229B SFB1205 3P 400AT 3P SSC1204 SSB1204 (LOCATED IN NPT LIFT STATION) LAB/ PRETREATMENT BLDG.) (LOCATED AT TO ESD-M1229-2 CONTINUED REFER NPT LIFT STATION) (LOCATED AT TO ESD-M1205-3 Page 163 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Utilities Work Order Form Official Purchasing Form Last updated 10/2017 ATTACHMENT B CERTIFICATE OF INSURANCE CONTRACTOR shall submit Certificate of Insurance in compliance with the Contract Documents. Page 164 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 CERTIFICATE HOLDER © 1988-2014 ACORD CORPORATION. All rights reserved. ACORD 25 (2014/01) AUTHORIZED REPRESENTATIVE CANCELLATION CERTIFICATE OF LIABILITY INSURANCE DATE (MM/DD/YYYY) JECT LOC PRO- POLICY GEN'L AGGREGATE LIMIT APPLIES PER: CLAIMS-MADE OCCUR COMMERCIAL GENERAL LIABILITY GENERAL LIABILITY PREMISES (Ea occurrence) $ DAMAGE TO RENTED EACH OCCURRENCE $ MED EXP (Any one person) $ PERSONAL & ADV INJURY $ GENERAL AGGREGATE $ PRODUCTS - COMP/OP AGG $ DED RETENTION $ CLAIMS-MADE OCCUR $ AGGREGATE $ UMBRELLA LIAB EACH OCCURRENCE $ EXCESS LIAB DESCRIPTION OF OPERATIONS / LOCATIONS / VEHICLES (Attach ACORD 101, Additional Remarks Schedule, if more space is required) INSR LTR TYPE OF INSURANCE POLICY NUMBER POLICY EFF (MM/DD/YYYY) POLICY EXP (MM/DD/YYYY) LIMITS WC STATU- TORY LIMITS OTH- ER E.L. EACH ACCIDENT E.L. DISEASE - EA EMPLOYEE E.L. DISEASE - POLICY LIMIT $ $ $ ANY PROPRIETOR/PARTNER/EXECUTIVE If yes, describe under DESCRIPTION OF OPERATIONS below (Mandatory in NH) OFFICER/MEMBER EXCLUDED? WORKERS COMPENSATION AND EMPLOYERS' LIABILITY Y / N AUTOMOBILE LIABILITY ANY AUTO ALL OWNED SCHEDULED HIRED AUTOS NON-OWNED AUTOS AUTOS AUTOS COMBINED SINGLE LIMIT BODILY INJURY (Per person) SUPP (10/00) SUPPLEMENT TO CERTIFICATE OF INSURANCE DATE NAME OF INSURED: (See Attached Named Insured List) Interstates Construction Services, Inc. 35 Interstates Engineering, Inc. dba IEI of Minnesota 34 Interstates Engineering, Inc. dba Iowa Interstates Eng 33 Interstates Engineering, Inc. dba CA IEI, Inc 32 Interstates Engineering, Inc. dba IEI of TX Inc 31 Harbor Insurance Trust, Inc. 30 Desert View Electric Services, LLC 29 InterFab, L.L.C. 28 IC of Wyoming, L.L.C. 27 Interstates Construction Services, Inc. dba IC of Oregon, Inc. 26 Interstates Construction Services, Inc. dba IC of Illinois, Inc. 25 Harbor Engineering Group, PLC 24 Harbor Consulting Group, Inc. 23 InterAir, LLC 22 Interstates Instrumentation, Inc. 21 Interstates Construction Services, Inc. dba IC of Texas, Inc. 20 Interstates Construction Services, Inc. dba IC of Arizona, Inc. 19 Interstates Construction Services, Inc. dba IC of Nebraska, Inc. 18 Harbor Management, LLC 17 Harbor Group Investments, LLC 16 Harbor Engineering Group, LLC 15 IEEC International, Inc. 14 IEEC International, Ltd. 13 Interstates Electric & Engineering Co., Inc. dba IEEC of Arizona 12 Interstates Electric & Engineering Co., Inc. dba IEEC of Oregon, Inc. 11 Interstates Electric & Engineering Co., Inc. dba IEEC of Illinois, Inc. 10 Interstates Electric & Engineering Co., Inc. dba IEEC of Texas, Inc. 9 Interstates Foundation 8 IEEC Enterprises Co. 7 IEEC Transportation & Leasing Co. 6 IEEC of California, Inc. 5 Interstates Construction Services, Incorporated 4 Interstates Electric & Engineering Co. 3 Interstates Control Systems, Inc. 2 Interstates Engineering, Inc. 1 The Harbor Group, Inc. 08/22/2017 Page 166 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 BODILY INJURY (Per accident) PROPERTY DAMAGE $ $ $ $ THIS IS TO CERTIFY THAT THE POLICIES OF INSURANCE LISTED BELOW HAVE BEEN ISSUED TO THE INSURED NAMED ABOVE FOR THE POLICY PERIOD INDICATED. NOTWITHSTANDING ANY REQUIREMENT, TERM OR CONDITION OF ANY CONTRACT OR OTHER DOCUMENT WITH RESPECT TO WHICH THIS CERTIFICATE MAY BE ISSUED OR MAY PERTAIN, THE INSURANCE AFFORDED BY THE POLICIES DESCRIBED HEREIN IS SUBJECT TO ALL THE TERMS, EXCLUSIONS AND CONDITIONS OF SUCH POLICIES. LIMITS SHOWN MAY HAVE BEEN REDUCED BY PAID CLAIMS. INSR ADDL WVD SUBR N / A $ $ (Ea accident) (Per accident) THIS CERTIFICATE IS ISSUED AS A MATTER OF INFORMATION ONLY AND CONFERS NO RIGHTS UPON THE CERTIFICATE HOLDER. THIS CERTIFICATE DOES NOT AFFIRMATIVELY OR NEGATIVELY AMEND, EXTEND OR ALTER THE COVERAGE AFFORDED BY THE POLICIES BELOW. THIS CERTIFICATE OF INSURANCE DOES NOT CONSTITUTE A CONTRACT BETWEEN THE ISSUING INSURER(S), AUTHORIZED REPRESENTATIVE OR PRODUCER, AND THE CERTIFICATE HOLDER. IMPORTANT: If the certificate holder is an ADDITIONAL INSURED, the policy(ies) must be endorsed. If SUBROGATION IS WAIVED, subject to the terms and conditions of the policy, certain policies may require an endorsement. A statement on this certificate does not confer rights to the certificate holder in lieu of such endorsement(s). The ACORD name and logo are registered marks of ACORD COVERAGES CERTIFICATE NUMBER: REVISION NUMBER: INSURED PHONE (A/C, No, Ext): PRODUCER ADDRESS: E-MAIL FAX (A/C, No): CONTACT NAME: NAIC # INSURER A : INSURER B : INSURER C : INSURER D : INSURER E : INSURER F : INSURER(S) AFFORDING COVERAGE SHOULD ANY OF THE ABOVE DESCRIBED POLICIES BE CANCELLED BEFORE THE EXPIRATION DATE THEREOF, NOTICE WILL BE DELIVERED IN ACCORDANCE WITH THE POLICY PROVISIONS. Rented/Leased Equipment Installation Floater X X 3P1894918 3Y1894918 09/01/18 09/01/18 Contractual Liability XCU Included 08/22/2017 500,000 ZUP14S6402917NF 09/01/18 Attn: Purchasing X City of Fort Collins USA Liability and Automobile Liability when required by written contract. The City of Fort Collins, CO, its officers, agents and employees are included as Additional Insureds on the General PO Box 260 X Attn: Scott Peterson N Fort Collins, CO 80521 1,000,000 X X 1,000,000 A 10,000 X 20,000,000 A 09/01/17 C A 22136 A 25674 09/01/17 21415 09/01/17 20,000,000 09/01/18 09/01/18 X tsternwdsm 3C1894918 X IMP592488111 GREAT AMER INS CO OF NY TRAVELERS PROP CAS CO OF AMER 2,000,000 3D1894918 EMPLOYERS MUT CAS CO 10,000 1-800-247-7756 (See Attached Named Insured List) 500,000 Interstates Construction Services, Inc. Holmes Murphy & Assoc - WDM 09/01/17 09/01/17 X X A 500,000 2,500,000 1,000,000 09/01/17 50625732 50625732 09/01/18 500,000 Sioux Center, IA 51250-0260 09/01/17 PO Box 9207 $2,500 Deductible $2,500 Deductible 09/01/18 B Des Moines, IA 50306-9207 P.O. Box 580 2,000,000 X 3E1894918 500,000 Page 165 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 CONTINUED REFER CONDUIT. CONDUIT. 1200AF 1200AF SFB1225 1000AT 3P DEWATERING BLDG.) (LOCATED AT TO ESD-M1225-2 CONTINUED REFER 1200AF 600AT SFB1229B 65KAIC SFB1205 65KAIC SFB1225 65KAIC 1500AT 3P 2000AF SS-LSIG 65KAIC SFB1204 SPACE SPACE Model: Layout1 ColorTable: gshade.ctb DesignScript: Carollo_Std_Pen_v0905.pen PlotScale: 2:1 User: LPitchley Plot Date: 07-SEP-2017 12:08:02 AM PROJECT NO. LAST SAVED BY: FILE NAME: 10545B10-ESD-EDD-06.dgn LPitchley LP ELECTRICAL SSB1204 ONE-LINE DIAGRAM CAH 1 KEY NOTES: 1 1 ESD-EDD-06 PROVIDE SPACE FOR FUTURE 800 AMP FRAME BREAKER. Page 162 of 166 TRANSFORMER AND SWITCHBOARD PROCUREMENT PACKAGE DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 eliminate pressure. Annual Pressure Relief Valve Check for dirt, debris and operation. Replace immediately if damage. Clean if dirty or clogged with debris. Annual Lightning Arresters Check for damage or breakage and an intact and tight ground connection. Replace damaged arresters and tighten or secure any lose ground connections. Annual Dissolved Gas Analysis Items to Inspect Points to be checked Remedial Action Frequency Oil Sample Take an oil sample and send it to a third party tester to check dissolved gas levels. Compare dissolved gas analysis results to the baseline result. Look for abrupt changes in dissolved gas levels. Any abrupt changes should be investigated immediately. Annual Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 27 Page 47 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Annual Tank Pressure Check that pressure/vacuum gauge does not remain at zero for an extended period of time. It is preferable that a given unit not cycle between negative and positive pressures on a daily basis. Commissioning pressures have been documented in a separate paper based on the top fluid temperature. Any observed readings lower than -2 psig or greater than +7 psig indicate a condition that can and should be corrected. If the pressure/vacuum gauge remains at zero for an extended period of time this may be evidence of air leakage in and out of the tank. A leak test should be performed by adding nitrogen to the airspace and observing for loss of pressure over an interval of a minimum of 12 hours. If the pressure is lost, locate the leak and repair immediately. Annual WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. De-energize transformer from a remote upstream source before opening cabinet and doing cabinet interior inspection or maintenance. Check that all transformer terminals and bushings have zero voltage. Ground transformer following industry accepted safe grounding practices. 26 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 46 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Conventional transformer oil, R-Temp, or Envirotemp™ FR3™ fluids can be filtered by means of a filter press. The filter press is effective for removing all types of foreign matter, including finely divided carbon and small amounts of moisture. The purifier equipment consists of a specifically proportioned filter press, a positive volume gear pump, driving motor, combined drip pan and mixing tank, necessary piping, valves, strainer, gauges and drying oven. Follow manufacturer’s instructions for purifier equipment operation. Filtration should be continued until the dielectric test of the insulating liquid is 26 kV or better. When filtering R-Temp or Envirotemp™ FR3™ fluid, the filtering equipment must be free of contaminants and other liquids. The presence of other liquids may alter the physical and electrical characteristics of R-Temp or Envirotemp™ FR3™ fluid. This could result in a reduction of fire point. Lowering insulating liquid level 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals. 2. If cover removal is required, remove cover as outlined in Tank Cover Removal and Installation section of this manual. 3. Prepare a clean, dry storage container to receive liquid. 4. Use pumps and hoses that have not been contaminated by contact with dissimilar liquids. Use a metal or non-rubber hose. Oil dissolves the sulfur found in rubber and will prove harmful to conductor material. 5. Attach pump intake line to drain valve on transformer tank. 6. Place output line nozzle on bottom of storage container. Do not permit liquid to splash into receiving container. Splashing will introduce air and moisture into liquid. 7. Do not lower liquid below top of core clamp unless absolutely necessary. Exposing coils may allow moisture to contaminate coil insulation. 24 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 44 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 application filled with conventional transformer oil. Basic recommended tests for Envirotemp™ FR3™ fluid are dielectric strength, moisture content, and flash and fire points. Envirotran transformer tanks are shipped from the factory with a dry nitrogen-filled headspace. Internal pressure should not be equalized with atmosphere by manually opening the pressure relief valve device unless access to Bay-O-Net fuses or other internal tank components is required. If internal service is required If the tank cover or manhole/handhole must be removed for internal service, exposure time to ambient air should be minimized. Avoid exposure times greater than 24 hours. Immediately after service is completed, replace the cover or manhole/handhole. The tank headspace must then be purged and recharged with dry nitrogen. Envirotran transformers are equipped with one or two 1/4” fill valves on the upper left and/or upper right corners of the face plate and are intended for the recharging process. The following steps should be followed when purging and recharging Envirotran transformers: 1. Verify that tank is grounded. De-energize transformer from a remote upstream source. Ground all bushings and terminals. 2. Release internal pressure by operating pressure relief device. 3. Fill headspace with dry nitrogen through one of the 1/4” fill valves to a pressure of 2-3 psig. 4. Release internal pressure by operating pressure relief device. 5. Refill headspace with dry nitrogen through one of the 1/4” fill valves to a pressure of 2-3 psig. Internal pressure must be maintained for at least four hours prior to transformer energization to verify seal integrity. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 23 Page 43 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 5/8”-11 Brass Nuts 75 ft-lbs. 1”-14 Brass Nuts 121 ft-lbs. Bushing Lead Block, 1/2” Steel Hardware 110 ft-lbs. Right Side of Cabinet Left Side of Tank Front of Cabinet Right Side of Tank A B A B A’ B’ B’ A’ Left Side of Cabinet Shim 1/4 to 3/8 inch Wedge 1 1/2 inch Figure 28. Cabinet removal diagram. CAUTION Potential Falling Object. Can cause personal injury or damage to transformer. Do not open cabinet doors when cabinet is removed from transformer tank. Opening cabinet doors will cause cabinet to fall forward. WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. De-energize transformer from a remote upstream source before opening cabinet and doing cabinet interior inspection or maintenance. Check that all transformer terminals and bushings have zero voltage. Ground transformer following industry accepted safe grounding practices. 22 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 42 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 ual. 9. Pressurize headspace through pressure relief valve coupling to insure that there are no leaks. The test pressure should not exceed 7 psig. The established pressure should be maintained for at least four hours to ensure that all seals are proper. 10. Re-install pressure relief valve. WARNING Explosive gas. Can cause severe injury, death, or damage to equipment. Before cutting open a weld- on tank cover, fill tank headspace with nitrogen gas. Keep nitrogen gas flowing while cutting. Keep tank headspace filled with nitrogen until cutting is finished. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 21 Page 41 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 4. Thoroughly clean tank and manhole/handhole cover to help prevent contamination of insulating liquid when removing manhole/handhole cover. Remove all dirt, grease, and moisture. 5. Relieve internal tank pressure by operating pressure relief valve. 6. Remove hardware (3/8” nuts using a 9/16” socket) attaching manhole/handhole cover to tank. 7. Gently pry cover upward. Do not allow cover gasket to come in contact with transformer insulating liquid. Allowing the gasket to contact the liquid will make it slippery and difficult to hold in position during cover installation. Lift cover straight up to prevent damage to cover, bolts, and tank gasket. 8. Note location and orientation (up/down) of each gasket section as they are removed from tank flange so they can be re-installed properly. Bolt-On manhole/handhole cover installation 1. Return gasket sections to their original positions and orientation. 2. Re-install manhole/handhole, using 25 ft-lbs. torque to tighten hardware. After installing all nuts, re-torque each nut to ensure proper torque is achieved. 3. Remove pressure relief valve and pressurize headspace through pressure relief valve coupling to ensure that there are no leaks. Test pressure should not exceed 7 psig. Established pressure should be maintained for at least four hours to ensure that all seals are proper. 4. Re-install access cover using 25 ft-lbs. torque to tighten access cover hardware. 5. Re-install pressure relief valve. 20 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 40 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 a remote upstream source before opening cabinet and doing cabinet interior inspection or maintenance. Check that all transformer terminals and bushings have zero voltage. Ground transformer following industry accepted safe grounding practices. CAUTION Elevated Pressure. Can cause personal injury or damage to transformer. Release internal pressure with pressure relief device before removing tank cover, manhole cover or handhole cover. WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. De-energize transformer from a remote upstream source before opening cabinet and doing internal tank inspection or maintenance. Check that all transformer terminals and bushings have zero voltage. Ground transformer following industry accepted safe grounding practices. CAUTION Elevated Pressure. Can cause personal injury or damage to transformer. Release internal pressure with pressure relief device before removing tank cover, manhole cover or handhole cover. WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. De-energize transformer from a remote upstream source before opening cabinet and doing internal tank inspection or maintenance. Check that all transformer terminals and bushings have zero voltage. Ground transformer following industry accepted safe grounding practices. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 19 Page 39 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 damage to equipment. Depending on configuration, Arc-Strangler fuses or switchblades may be energized even when in the “open” position. Refer to catalog section 240-60 for further information. WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. De-energize transformer from a remote upstream source before servicing or operating surge arresters or disconnect switches. Check that all transformer terminals and bushings have zero voltage. Ground transformer following industry accepted safe grounding practices. CAUTION Excessive test voltage can damage surge arresters. Disconnect surge arresters before running impulse or applied potential tests on the transformer. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 17 Page 37 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 (32 °F) for R-Temp fluid or less than -10 °C (14 °F) for Envirotemp™ FR3™ fluid, viscosity is reduced, which may reduce make and break capabilities of loadbreak devices. Below these temperatures, under-oil loadbreak accessories should not be used to make or break a load. Instead, de-energize transformer from a remote upstream source before operating under-oil loadbreak devices. 16 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 36 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 terminals protects against situations such as a standby generator energizing transformer from the secondary circuit. • Follow industry accepted safety practices. Utilize protective clothing and equipment when working with loadbreak equipment. WARNING Three-phase pad-mounted transformers use conventional transformer oil, R-Temp fluid, or Envirotemp™ FR3™ fluid for an insulating liquid. When the insulating liquid temperature is less than -20 °C (-4 °F) for conventional transformer oil, less than 0 °C (32 °F) for R-Temp fluid or less than -10 °C (14 °F) for Envirotemp™ FR3™ fluid, viscosity is reduced, which may reduce make and break capabilities of loadbreak devices. Below these temperatures, under-oil loadbreak accessories should not be used to make or break a load. Instead, de-energize transformer from a remote upstream source before operating under-oil loadbreak devices. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 15 Page 35 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 loadbreak tap-changers, dual-voltage switches, or delta-wye switches. CAUTION Excessive current. Can cause damage to transformer winding. When dual-voltage or delta-wye switches are set to connect transformer windings in parallel, tap-changers must be in the position shown on the transformer nameplate. 14 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 34 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 from a remote upstream source before operating non- loadbreak tap-changers, dual-voltage switches, or delta-wye switches. 12 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 32 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 transformer terminals following industry accepted safe grounding practices. Grounding secondary terminals protects against situations such as a standby generator energizing transformer from the secondary circuit. • Follow industry accepted safety practices. Utilize protective clothing and equipment when working with loadbreak equipment. WARNING Three-phase pad-mounted transformers use conventional transformer oil, R-Temp fluid, or Envirotemp™ FR3™ fluid for an insulating liquid. When the insulating liquid temperature is less than -20 °C (-4 °F) for conventional transformer oil, less than 0 °C (32 °F) for R-Temp fluid or less than -10 °C (14 °F) for Envirotemp™ FR3™ fluid, viscosity is reduced, which may reduce make and break capabilities of loadbreak devices. Below these temperatures, under-oil loadbreak accessories should not be used to make or break a load. Instead, de-energize transformer from a remote upstream source before operating under-oil loadbreak devices. CAUTION Always fully cover and lock external visible loadbreak switch window during operation. Failure to cover and lock this window could cause personal injury. Before operating the on/off/ground switch, it is important to ensure the transformer tank has been fully grounded. Always check fluid temperature before operating loadbreak devices. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 11 Page 31 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 inside the tank. 8 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 28 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 remote upstream source. FUSEHOLDER LATCH HANDLE FUSE CARTRIDGE HOLDER FUSE LINK FUSE CARTRIDGE END PLUG GASKET SEAL CONTACT FLARE TULIP TIP Figure 8. Bay-O-Net fuse assembly. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 7 Page 27 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 tank wall. WARNING Hazardous voltage. Can cause severe injury, death, or damage to equipment. Ground transformer following industry-accepted safe grounding practices before making other electrical connections. De-energize power distribution wires that will be connected to transformer. Verify that wires are de-energized at the transformer before connecting to transformer. Figure 3. Grounding pad. 4 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 24 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 Do not remove liquid level plug (see Figure 2) before venting transformer to zero pressure. Pull ring on pressure relief valve to relieve pressure. Figure 2. Liquid level plug. WARNING Fire Hazard. Energizing transformer in ambient temperatures below -20 °C can result in fire and cause severe personal injury or death. Contact your Eaton representative for further instructions on energizing transformer in ambient temperatures below -20 °C. CAUTION Before opening the transformer tank for Pre-Service Inspection, read the Insulating Liquid Maintenance section in this manual. This section explains safety precautions that should be taken and gives instructions on how to prevent insulating liquid contamination. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 3 Page 23 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 pressure may indicate a leak at a gasket seal or tank seam, and require further investigation. To leak test transformer, remove the pressure relief valve (see Figure 1) and pressurize the headspace to ensure that there are no leaks. The test pressure should not exceed 7 psig. The established pressure should be maintained for at least four hours to ensure that all the seals are proper. Figure 1. Pressure relief valve. WARNING Fire Hazard. Non-level installation of transformer can result in fire and cause severe personal injury or death. Prepare transformer installation site such that transformer does not tilt more than two (2.0) degrees from horizontal while the transformer is in service at the site. 2 Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 Page 22 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 transformer tank. Lifting chain or cable angles should not be over 30° from vertical. Otherwise, spreaders should be used to hold the lifting cables apart to avoid any bending of the structure or lifting lugs. Do not attempt to lift the transformer by placing a continuous loop of chain or cable around the unit or lifting lugs. This can damage the transformer and can cause accidents resulting in serious personal injury. If the transformer cannot be lifted by crane, it may be skidded or moved by rollers. Using jacks Place jacks under the tank base on the open ends of the transformer tank. Jacking pads are provided for transformers with bases greater than 6”. Do not place jacks under radiators or terminal compartment frames. When jacking a transformer for insertion of rollers underneath it, ensure that four jacks are used and that two adjacent corners are raised simultaneously and evenly to avoid warping the base. When using rollers, use as many as necessary to distribute the weight uniformly. Do not attach pulling lines to moldings or other sheet metal parts of the transformer. IMPORTANT Do not Exceed Transformer Ratings. Transformers should be operated only at the ratings specified on the transformer nameplate. Prolonged overload operation will measurably shorten the projected service life of a mineral oil-filled transformer. Eaton’s Cooper Power™ series PEAK™ transformers may help to extend insulation life and can be operated at higher capacities than traditional units while still exceeding ANSI® standard insulation life. WARNING Heavy Equipment. Improper handling can cause severe injury, death, or damage to transformer. Before moving the transformer, read the handling instructions provided in this manual. Three-phase pad-mounted compartmental type installation and maintenance instructions MN202001EN August 2015 1 Page 21 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3 personnel and are not a substitute for adequate training and experience in safety procedures. Failure to properly select, install or maintain power distribution and transmission equipment can result in death, severe personal injury, and equipment damage. G122.3 This manual may contain four types of hazard statements: DANGER Indicates an imminently hazardous situation which, if not avoided, will result in death or serious injury. WARNING Indicates a potentially hazardous situation which, if not avoided, could result in death or serious injury. CAUTION Indicates a potentially hazardous situation which, if not avoided, may result in minor or moderate injury. CAUTION: Indicates a potentially hazardous situation which, if not avoided, may result in equipment damage only. Hazard Statement Definitions Page 20 of 166 DocuSign Envelope ID: 6D688FDD-109D-4B8E-823E-C47C4FA50EC3