S02_ 36C25925Q0292_1.docx

36C25925Q0292

PAGE 1 OF

1. REQUISITION NO.

2. CONTRACT NO.

3. AWARD/EFFECTIVE DATE

4. ORDER NO.

5. SOLICITATION NUMBER

6. SOLICITATION ISSUE DATE

a. NAME

b. TELEPHONE NO. (No Collect Calls)

8. OFFER DUE DATE/LOCAL

TIME

9. ISSUED BY

CODE

10. THIS ACQUISITION IS

UNRESTRICTED OR

SET ASIDE:

% FOR:

SMALL BUSINESS

HUBZONE SMALL

BUSINESS

SERVICE-DISABLED

VETERAN-OWNED

SMALL BUSINESS

WOMEN-OWNED SMALL BUSINESS

(WOSB) ELIGIBLE UNDER THE WOMEN-OWNED

SMALL BUSINESS PROGRAM

EDWOSB

8(A)

NAICS:

SIZE STANDARD:

11. DELIVERY FOR FOB DESTINA-

TION UNLESS BLOCK IS

MARKED

SEE SCHEDULE

12. DISCOUNT TERMS

13a. THIS CONTRACT IS A

RATED ORDER UNDER

DPAS (15 CFR 700)

13b. RATING

14. METHOD OF SOLICITATION

RFQ

IFB

RFP

15. DELIVER TO

CODE

16. ADMINISTERED BY

CODE

17a. CONTRACTOR/OFFEROR

CODE

FACILITY CODE

18a. PAYMENT WILL BE MADE BY

CODE

TELEPHONE NO.

UEI:

EFT:

PHONE:

FAX:

17b. CHECK IF REMITTANCE IS DIFFERENT AND PUT SUCH ADDRESS IN OFFER 18b. SUBMIT INVOICES TO ADDRESS SHOWN IN BLOCK 18a UNLESS BLOCK BELOW IS CHECKED

SEE ADDENDUM

19.

20.

21.

22.

23.

24.

ITEM NO.

SCHEDULE OF SUPPLIES/SERVICES

QUANTITY

UNIT

UNIT PRICE

AMOUNT

(Use Reverse and/or Attach Additional Sheets as Necessary)

25. ACCOUNTING AND APPROPRIATION DATA

26. TOTAL AWARD AMOUNT (For Govt. Use Only) 27a. SOLICITATION INCORPORATES BY REFERENCE FAR 52.212-1, 52.212-4. FAR 52.212-3 AND 52.212-5 ARE ATTACHED. ADDENDA

ARE

ARE NOT ATTACHED.

27b. CONTRACT/PURCHASE ORDER INCORPORATES BY REFERENCE FAR 52.212-4. FAR 52.212-5 IS ATTACHED. ADDENDA

ARE

ARE NOT ATTACHED

28. CONTRACTOR IS REQUIRED TO SIGN THIS DOCUMENT AND RETURN _______________

29. AWARD OF CONTRACT: REF. ___________________________________ OFFER

COPIES TO ISSUING OFFICE. CONTRACTOR AGREES TO FURNISH AND

DATED ________________________________. YOUR OFFER ON SOLICITATION

DELIVER ALL ITEMS SET FORTH OR OTHERWISE IDENTIFIED ABOVE AND ON ANY

(BLOCK 5), INCLUDING ANY ADDITIONS OR CHANGES WHICH ARE

ADDITIONAL SHEETS SUBJECT TO THE TERMS AND CONDITIONS SPECIFIED

SET FORTH HEREIN IS ACCEPTED AS TO ITEMS:

30a. SIGNATURE OF OFFEROR/CONTRACTOR 31a. UNITED STATES OF AMERICA (SIGNATURE OF CONTRACTING OFFICER) 30b. NAME AND TITLE OF SIGNER (TYPE OR PRINT) 30c. DATE SIGNED 31b. NAME OF CONTRACTING OFFICER (TYPE OR PRINT) 31c. DATE SIGNED

AUTHORIZED FOR LOCAL REPRODUCTION

(REV. NOV 2021)

PREVIOUS EDITION IS NOT USABLE

Prescribed by GSA - FAR (48 CFR) 53.212

7. FOR SOLICITATION

INFORMATION CALL:

STANDARD FORM 1449

SOLICITATION/CONTRACT/ORDER FOR COMMERCIAL PRODUCTS AND COMMERCIAL SERVICES

OFFEROR TO COMPLETE BLOCKS 12, 17, 23, 24, & 30

575-25-1-6043-0004

36C259-25-AP-5297

36C25925Q0292 03-24-2025 Crystal Volmar, crystal.volmar@va.gov

04-11-2025

5:00 PM

MDT

36C259 Department of Veterans Affairs Network Contracting Office

NCO 19

6162 South Willow Drive, Suite 300 Greenwood Village CO 80111

X

238210 $19 Million

N/A

Department of Veterans Affairs Western Colorado Health Care System 2121 North Avenue

Grand Junction CO 81501 36C259 Department of Veterans Affairs Network Contracting Office

NCO 19

6162 South Willow Drive, Suite 300 Greenwood Village CO 80111

Financial Service Center PO Box 149971 Austin TX 78714-9971 877-353-9791 512-460-5221

See CONTINUATION Page Electrical Power Distribution System Testing, Inspection, Preventative Maintenance (PM) and Certification Services

The contractor shall provide testing, inspection, preventative maintenance adjustment and certification of the electrical distribution systems at the Western Colorado Health Care System in Grand Junction, Colorado.

All questions must be submitted to crystal.volmar@va.gov and received no later than 5:00pm MST on 03/28/25.

An amendment will be posted no later than 5:00pm MST 04/01/25 with answers to the submitted questions.

All offers must be submitted to crystal.volmar@va.gov and received no later than 5:00pm MST on 04/11/25.

Vendor must be registered and verified in www.sam.gov and https://veterans.certify.sba.gov/ at quote submission.

See CONTINUATION Page

Table of Contents

SECTION B - CONTINUATION OF SF 1449 BLOCKS

B.1 CONTRACT ADMINISTRATION DATA

1. Contract Administration: All contract administration matters will be handled by the following individuals:

a. CONTRACTOR:

b. GOVERNMENT: Contracting Officer 36C259

Network Contracting Office

NCO 19

6162 South Willow Drive, Suite 300 Greenwood Village CO 80111

2. CONTRACTOR REMITTANCE ADDRESS: All payments by the Government to the contractor will be made in accordance with:

3. INVOICES: Invoices shall be submitted in arrears:

4. GOVERNMENT INVOICE ADDRESS: All Invoices from the contractor shall be submitted electronically in accordance with VAAR Clause 852.232-72 Electronic Submission of Payment Requests.

B.2 STATEMENT OF WORK

Department of Veterans Affairs (VA) Western Colorado Health Care System (WCHCS) (SOW) for Testing, Inspection, Preventive Maintenance (PM), and Certification for the Electrical Power Distribution System

1. Purpose The WCHCS main campus is located at 2121 North Avenue, Grand Junction, CO, 81501. The WCHCS campus consists of 16 buildings and approximately 310,000 square feet. The voltages on site include 13.2 kV, 277/480 V, and 120/208 V. The WCHCS has a requirement for testing, inspection, preventative maintenance (PM) adjustment and certification of the electrical distribution systems. This testing occurs on a semi-annual, annual, and tri-annual basis.

2. Objectives To increase system reliability and eliminate any unplanned downtime by completing all required inspections, testing, and maintenance on the Electrical System in accordance with the standards listed in 3.6.

3. General

3.1. The Contractor shall perform an electrical coordination and arc-flash study in strict compliance with National Fire Protection Agency (NFPA) 70E - Standard for Electrical Safety in the Workplace, 2023 edition, and table 242-2001 - Recommended Practice for Protection and Coordination of Industrial and Commercial Power Systems. Survey work shall be accomplished on energized equipment unless an outage is required due to specific equipment safety conditions. Any outages, even momentary, shall be after normal working hours or on weekends/holidays. All requests for outages must be submitted in writing to the Contracting Officer’s Representative (COR) and approved by the Chief Engineer per paragraph 6.2. Requesting a power outage does not guarantee that the requested time will be approved, facility operations continue after normal business hours and take precedent over construction. Contractor shall provide adequate staffing to keep scheduled outages to a maximum of two (2) hours per Automatic Transfer Switch (ATS). During the 2-hour shutdown, contractor shall complete all inspections that require a power outage on that system that includes all emergency powered panels downstream of the ATS.

3.2. After award the contractor shall conduct a site survey with the Chief Engineer and Engineering staff prior to the commencement of any work performance. The contractor shall use this meeting to introduce their team and define the process and schedule that will be executed to complete the required services. The Contractor shall obtain the necessary one-line diagrams and drawings and field information. At the completion of the site survey, the contractor shall again conduct a short briefing with the Chief Engineer and staff to discuss any major problems or life-threatening issues if any are discovered during the survey.

3.3. The COR shall monitor the technical aspects of the contract and report any deficiencies or abnormalities to the Contracting Officer (CO). In no event shall the COR change any of the terms and conditions of the contract. Any changes or modifications to the contract shall be made only by the CO and/or Contract Administrator (CA), pursuant to a properly executed contract action.

3.4. This SOW establishes baseline requirements pertaining to semi-annual, annual, and tri-annual inspection, testing, and preventative/corrective maintenance service.

3.5. Supply all labor, supervision, tools, materials, equipment, and industry expertise to complete the requirements listed in section 4.

3.6. All work performance shall be completed in compliance with the latest versions of the following Standards and Guidelines unless a conflict arises concerning requirements for maintenance or testing, then the most stringent requirement shall apply, unless otherwise directed by this contract or the CO:

· Veteran’s Health Administration (VHA) Directive 1028.

· NFPA 70B

· NFPA 70E

· NFPA 99

· NFPA 101

· American National Standards Institute (ANSI)/International Electrical Testing Association (NETA) Maintenance and Testing Specification (MTS)

· The Joint Commission (TJC) 02.05.01

· Manufacturer’s requirements

3.7. All tasks, responsibilities, and deliverables are assumed to be the purview of the Contractor unless otherwise stated.

4. Mandatory Tasks and Deliverables

4.1 CLIN 0001 – Semi-Annual Service. Each year, complete two (2) semi-annual testing and maintenance services on the following equipment in accordance with the manufacturer’s requirements. This testing will be accomplished on energized equipment.

4.1.1. 13.2 kV Automatic Transfer Operator (ATO). 1) Inspect for damage, missing components, missing labels, securing integrity, door operation, malfunctioning components, moisture, and contamination. 2) Disengage the ATO and verify the electronics are operating properly. 3) Verify the ATO program software is running the current version and that the equipment switches over properly if one of the 3-phase legs drops out.

4.1.2. 13.2 kV Switchgear. Equipment to be serviced consists of one (1) Metal-clad Switchgear. 1) Inspect for damage, missing equipment, missing or illegible labels, securing integrity, operation of doors, malfunctioning equipment, moisture or contamination, and visually inspect ground terminations. Contractor shall conduct an infrared scan of all wiring compartments. 2) Verify all switch handles are functional. 3) Measure the load current and report any that exceed the ampere rating of the breaker. 4) Inspect the insulation system on the primary bus and assemblies. 5) Test insulation on each bus, phase-to-phase, and phase-to-ground with a suitable mega-ohm meter. 6) Affix inspection label and verify labels for rotation and arc fault labels are present and legible, replace as needed.

4.1.3. Other 13.2 kV Distribution Equipment. Equipment to be serviced consists of two (2) sectionalizers and eight (8) terminal cabinets. 1) Inspect for damage, missing equipment, missing or illegible labels, securing integrity, operation of doors, malfunctioning equipment, moisture or contamination. 2) Conduct an infrared scan of all wiring compartments. 3) Verify each cabinet is stenciled with the cabinet designation. 4) Identify feeds and designations on the sectionalizer cabinets and stencil designation on each door. 5) Stencil the equipment designation and medium voltage loop number on the exterior of the equipment. 6) For sectionalizers, also label the feed destination for each of the three (3) fused sections. 7) Measure the load current and report any that exceed the ampere rating of the breaker. 8) Inspect the insulation system on the primary bus and assemblies. 9) Test insulation on each bus, phase-to-phase, and phase-to-ground with a suitable mega-ohm meter. 10) Affix inspection label and verify labels for rotation and arc fault labels are present and legible, replace as needed.

4.1.4. Oil Filled Transformers. Equipment to be serviced consists of thirteen (13) 13.2kV primary oil filled transformers. All transformers are less than fifteen (15) years old and do not contain any polychlorinated biphenyl (PCB). 1) Conduct an infrared scan of the primary and secondary compartments. 2) Test for positive nitrogen blanket and make corrections as needed. 3) Inspect for leaks, oil pools, oil stains, damage, missing equipment, missing or illegible labels, securing integrity, operation of doors, malfunctioning equipment, moisture or contamination, and visually inspection ground terminations. 4) Correct minor deficiencies and clean where appropriate. 5) Affix inspection label and verify labels for rotation and arc fault labels are present and legible, replace as needed.

4.1.5. Deliverables for CLIN 0001. 1) All inspection and testing shall be completed in compliance with the requirements in section 3.6. 2) Service work shall be completed in a method that maintains operational integrity of the electrical system during testing. 3) Provide the COR a copy of a field service report at the end of each service day and shall identify all deficiencies discovered. The COR shall review each deficiency and determine if the repair can be completed during the next service date, or if an emergency repair is needed. 4) If an emergency repair is required, the COR shall request a quote be provided. All repair quotes shall be reviewed by the COR and approved by the CO to ensure pricing is fair and reasonable. WCHCS reserves the right to have the repairs performed in-house or pursue other alternate options. 5) If the WCHCS selects the contractor to complete the repairs, a modification to this contract will be required. 6) Within seven (7) calendar days after the completion of service, the Contractor shall provide the COR a final service report. The report shall include results from all tests performed, all parts cleaned, adjusted, calibrated, or replaced, and all deficiencies identified and a list of all open and closed deficiencies.

4.2. CLIN 0002 - Annual Ultrasound and Infrared Thermography Inspection. Complete an ultrasound and infrared thermography imaging of energized electrical system components per the latest one-line drawings. The scanning shall include all equipment from Utility Service Providers (USP) service entry primary distribution panel and disconnects. Objective of this work is to detect any loose, broken, or corroded connections in the system. Problem connections shall be replaced with new connectors, and/or tightened using a calibrated torque wrench to meet the equipment manufacturers’ specifications. Testing shall include, but not limited to the following system components:

· Switch Gear

· Transformers

· Service Disconnects

· Transfer Switches

· Bus Runs

· Motors / Pumps / Bearings

· Motor Control Centers

· Breaker Panels

· Variable Frequency Drives (VFD’s) / Starters

4.2.1. Deliverables for CLIN 0002. 1) Ensure the use calibrated testing equipment used for all measurements of the electrical system. Contractor shall provide calibration certifications upon request of the COR. 2) Within 10 business days after testing, prepare and deliver to the COR a final report for the annual testing in accordance with NFPA 70B; 2023, Chapter 8. The final report shall include and highlight all new devices discovered during the inspection. Each new device shall be identified by device type, equipment #, or model and serial #, building #, floor #, room #, and panel #, if available. 3) Provide to the COR, three (3) physical copies of the final report and electronic copies of all inspections/tests, results of tests, and recommendations for compliance of the system. 4) The report shall detail discrepancies identified during the Ultrasound inspection and discrepancies shall be accompanied by graphical representation of deficiency measurements observed during inspection. 5) The report shall detail discrepancies identified during the infrared thermography inspection and discrepancies shall be accompanied by photographic images showing the discrepancies observed during inspection.

4.3. CLIN 0003 Three (3) Year System Inspection, Testing, and Studies. Complete a Tri-annual service of the Electrical Distribution System and system equipment by the month of May in order to avoid heavy summer electrical loads. This service is intended to be de-energized and will be conducted on weekends and after hours to minimize disruption to the hospital. The study is to include the items below:

· Short Circuit Study

· Shock Hazard Analysis

· Arc Flash Hazard Analysis

· Load-Flow Study

· Coordination Site Survey

· Coordination Analysis

· Coordination Final Report and Breaker Adjustment

· Reliability Study

· Reliability Analysis

· Equipment Preventative Maintenance Inspection

· Equipment Preventative Maintenance Final Report

4.3.1. Scope of Work for the Tri-annual of the services. A test of the Essential Electrical System (ESS) (or other Level 1 Electronic Performance Support System (EPSS), as defined in NFPA 110) that lasts for 4 hours continuously must be planned and executed every 36 months, in accordance with the requirements of NFPA 99 and NFPA 110. This test must meet The Joint Commission requirements to be under load of at least 30 percent of the nameplate load. Locations at high altitude where generator capacity is to be derated, 30 percent of the derated generator capacity should be used (versus 30 percent of the nameplate value). NOTE: The Joint Commission requires a 4-hour generator test under load (dynamic or static) that is at least 30 percent of the nameplate rating of the generator once every 36 months. If a VA medical facility’s generator requires an annual load bank to comply with Element of Care (EC).02.05.07 EP 5, it will also require a load bank every 36 months for 4 hours to comply with EC.02.05.07 EP 8. It is important to note the annual load bank only exceeds 30 percent for 1.5 hours.

4.3.1.1. Short Circuit and Coordination Study. Prepare a complete Short Circuit and Coordination Study including voltage drop calculations on the entire electrical system/s (both normal and emergency) beginning at the incoming utility electrical service (for the normal system) and at the emergency generators (for the emergency system) and continue through to each branch circuit panelboard, motor control center or motor control panel in each building. The study shall include, but not limited to a system one-line diagram; Short Circuit and ground fault analysis, protective coordination plots, voltage drop calculations and the testing and tasks outlined in paragraph 4.3.1 and all sub paragraphs.

4.3.1.2. One-line drawings. Create new one-line diagrams that identify the schematic wiring of the electrical distribution system for each building. Include all electrical equipment and wiring protected by the over current devices and shall include the following specific information: 1) calculated short circuit values at each bus, 2) breaker and fuse ratings, 3) transformer kVA, 4) voltage ratings and wiring connections, 5) voltage at each bus, 6) identification of each bus, 7) conduit material, feeder sizes and lengths, and 8) generator kW and voltage ratings.

4.3.1.3. Voltage Drop Measurements. 1) Provide actual voltage drop measurements for all three-phase branch and feeder circuits. 2) Show actual voltages at each bus and voltage drops on each feeder. 3) Provide a system one-line diagram which clearly identifies individual equipment busses, bus numbers, cable and bus connections and other circuit information. 4) Provide a separate section or table which provide an evaluation of the actual voltage drops with recommendations for improvements where voltage drops exceed the allowable National Electrical Code (NEC) limits.

4.3.2. 13.2 kV ATO. 1) Provide testing and maintenance for one (1) 13.2 kV S&C PMH switch per manufacturers guidelines. 2) Conduct an infrared scan of the wiring compartment.

Inspect for and report damage, missing equipment, missing labels, security to foundation, operation of doors, loose connections, malfunctioning equipment, moisture, or contamination. 3) Affix inspection label, verify rotation label, new VA provided equipment label, and arc fault labels are present and legible. Relabel as needed. 4) De-energize entire substation, clean all insulating surfaces, and clean and dress all contacts. Measure contact resistance in micro-ohms, Megger each phase-to-ground. Record all readings. Clean and inspect cubicle, torque all untapped connections to manufacturer’s specifications, and lubricate, as necessary. 5) Verify loss of power transfer and loss of phase transfer from primary to secondary and vice versa. Coordinate with third party utility provider during this test to deenergize and reenergize the equipment. 6) Verify software is current and upgrade software as required.

4.3.3. 13.2 kV SWITCHGEAR. Equipment to be inspected consists of one (1) Metal-clad Switchgear.

4.3.3.1. General: 1) Inspect for and report damage, missing equipment, missing labels, security to foundation, operation of doors, loose connections, malfunctioning equipment, moisture, or contamination, visually inspect ground terminations. 2) Conduct an infrared scan of all wiring compartments. 3) Verify all switch handles are functional. 4) Load current - Measure and report any that exceeds the ampere rating of the breaker. Record all readings and include in the comprehensive report. 5) Inspect the insulation system on the primary bus and assemblies. Test insulation on each bus, phase-to-phase, and phase-to-ground with suitable mega-ohm meter. Record values, report deficiencies. Inspect each bus and connection bars for overheating and loose connections. Check if bus is operating at a higher load than its rating. 6) Torque all connections to manufacturer’s specifications. 7) De-energize entire substation, clean all insulating surfaces, and clean and dress all contacts. Measure contact resistance in micro-ohms, Megger each phase-to-ground. Record all readings. Clean and inspect cubicle, torque all untapped connections to manufacturer’s specifications, and lubricate, as necessary. 8) Check nuts and bolts for tightness. Check pins or cotter pins, determine they are in place, and that all cotter pins have sufficient spread. Reset or replace defective pins or cotter pins. Check mechanism rods and moving parts for binding. Operate the disconnect switch several times for a functional test of all parts. Lightly lubricate bearing points. 9) Inspect the elevating and lowering mechanisms of metal-clad switchgear and dropout devices; perform an operational check and lubricate. 10) Inspect changing mechanisms, shutters, and interlock to assure that they close when the breaker is removed. All interlocks shall be inspected. 11) Examine contacts - check the amount of wipe in closing and opening. Contacts should be clean and bright. Clean and dress contacts as required. Check condition of arcing contacts for pitting and check condition of conductors. Damaged, burned or pitted laminated contacts shall be reported. 12) Perform a functional check of the control switches and the closing relays. 13) Meters, Relays, and Instruments shall be examined and checked for calibration. Report instruments out of calibration or that have broken glass or damaged cases. Clean, inspect, test, and calibrate over current relays. Remove each relay from its case. Clean, inspect, and tighten all connections. Apply three multiples of relay tap current to each relay to verify manufacturer’s time current characteristics. Test each relay for instantaneous pickup. Affix dated and initialed calibration seals to all meters and instruments. 14) Control and Instrument Transfer Switches - Check operation of control and instrument transfer switches; inspect all switch contacts. Equipment controlled by the switch that is infrequently operated shall be inspected, including an operational check of the controlled device. 15) Inspect test blocks for loose contacts and cracked bases or covers. 16) Inspect instrument transformers primary and secondary connections, grounding (of both frame and secondary) and potential transformer fuses. Tighten all loose connections. 17) Test operation of differential relay. 18) Burned out lamps shall be replaced. VA will provide contractor with replacement bulbs or LED indicators. 19) Correct minor deficiencies and clean where appropriate. 20) Affix inspection label, rotation, and arc fault labels.

4.3.3.2. For All five (5) medium voltage breakers: 1) Draw or rack each breaker from its cell. Remove arc chutes, clean, inspect, and adjust all contacts, as necessary. 2) Measure and record contact resistance in micro-ohms and clean all insulating surfaces. 3) Megger phase-to-phase, and phase-to-ground and measure contact resistance in micro-ohms. 4) Clean and inspect each breaker. Clean and dress all contact surfaces and lubricate, as necessary. 5) Electrically close and trip each breaker with control switch. 6) Manually close and trip each breaker with each of its protective devices. Test trip function using primary injection method. 7) Record testing results and include in the comprehensive report. 8) Check that Tripping devices and trip latches move freely, and that the armature of each over current trip device has sufficient freedom of travel to assure release of the breaker latch. Check the calibration and reset, if necessary, to avoid nuisance tripping.

4.3.4. OTHER 13.2 kV DISTRIBUTION EQUIPMENT. Equipment to be inspected consists of two (2) sectionalizers and eight (8) terminal cabinets. 1) Perform insulation resistance test (using test voltage between 10 kV and 13.8 kV) on all 13.2 kV bus bars. Record results. 2) Check and record ground resistance. 3) Conduct an infrared scan of the wiring compartment. 4) Inspect for and report damage, missing equipment, missing labels, security to foundation, operation of doors, loose connections, malfunctioning equipment, moisture, or contamination. 5) Stencil cabinet designation on each cabinet, Identify feeds and destination for the sectionalizer cabinets, stencil designations on each door. 6) Affix inspection, rotation, and arc fault labels. 7) Stencil the equipment designation and medium voltage loop number on the exterior of the equipment. For sectionalizers, also label the feed destination for each of the 3 fused sections.

4.3.5. 13.2 kV CONDUCTOR CABLING. Equipment to be inspected consists of forty-five (45) 13.2 kV cables. 1) Inspect for and report damage, missing equipment, missing labels, loose connections, malfunctioning equipment, moisture, or contamination and visually inspect ground terminations. 2) Label both ends of all 13.2 kV cabling with colored tape and a wire label indicating the location of the remote end. Tape colors shall be: A=red, B=white, C=blue. All cables shall be positively identified before labeling. After labeling, land all cables on the proper terminal (A=red, B=white, C=blue) at both ends to the maximum extent possible. If unable to properly land cables, notify the COR. If this results in a change in rotation change terminations at the transformer secondary terminals.

4.3.6. OIL-FILLED TRANSFORMERS (NON-PCB). Equipment to be inspected consists of thirteen (13) 13.2 kV primary oil filled transformers. All transformers are less than ten (10) years old and do NOT contain polychlorinated biphenyl (PCB). 1) Measure and record secondary voltage. 2) Measure and record load current. 3) Check and record phase rotation at secondary lugs. 4) Check and record temperature readings and fluid levels. Verify that readings are within safe limits. Reset temperature gauges. 5) Check and record ground resistance. 6) Conduct an infrared scan of the primary and secondary compartments. 7) Test for positive nitrogen blanket, make corrections if required.

Inspect for and report leaks, oil pools, oil stains, damage, missing equipment, missing labels, security to foundation, operation of doors, loose connections, malfunctioning equipment, moisture, or contamination and visually inspect ground terminations. 8) Sample all insulating liquid and report results numerically and with narrative interpretation. Testing shall include dissolved gas—in—oil analysis for volume (U of hydrogen, methane, ethane, ethylene, acetylene, carbon monoxide, carbon dioxide, nitrogen, oxygen, total gas, total combustible gas, and equivalent TCG reading (U; also, moisture in oil (ASTN 0—15338), interfacial tension (ASTM 0-971), acid number (ASTM 0—974), color number (ASTM 0—1500), dielectric breakdown voltage (ASTM 0—877), and specific gravity (ASTM D-l298). 9) Correct minor deficiencies and clean where appropriate. 10) Torque lugs if indicated by IR scan. 11) Affix inspection, rotation, and arc fault labels. 12) Verify the equipment designation and medium voltage loop number stenciling on the exterior of the equipment.

4.3.7. GENERATORS-EMERGENCY POWER SYSTEM ANALYSIS. Equipment to be inspected consists of four (4) diesel-powered standby generators. 1) Provide a narrative describing the existing emergency power systems. Include a description of each emergency generator, physical location, size (kW and ampacity), voltage, phasing, age, and overall condition. 2) Provide a summary of the average loading on each generator based on data provided by the WCHCS or by measurements taken while under load. 3) Develop load projections based on discussions with engineering staff on projected growth and future projects. 4) Provide a qualitative narrative on the suitability of the existing generators to meet current and future demands, recommendations shall be provided in the final study.

4.3.8. GENERATOR DOCKING STATIONS. Equipment to be inspected consists of five (5) generator docking stations. 1) Check and record phase rotation at main lugs. 2) Conduct an infrared scan of the wiring compartment. 3) Inspect for and report damage, missing equipment, missing labels, security to foundation, operation of doors, loose connections, malfunctioning equipment, moisture, or contamination and visually inspect ground terminations. 4) Correct minor deficiencies and clean where appropriate. 5) Torque lugs if indicated by IR scan. 6) Affix inspection, rotation, new VA provided equipment label, and arc fault labels.

4.3.9. Automatic Transfer Switch (ATS). Equipment to be inspected consists of seventeen (17) ATSs. 1) Check and record phase rotation at main lugs. 2) Conduct an infrared scan of wiring compartment while under utility power and again under generator power. 3) Conduct an infrared scan of the wiring compartment while on normal power and while on generator power. 4) Inspect for and report damage, missing equipment, missing labels, security to foundation, operation of doors, loose connections, malfunctioning equipment, moisture, or contamination and visually inspect ground terminations. 5) Correct minor deficiencies and clean where appropriate. 6) Torque lugs if indicated by IR scan. 7) Affix inspection, rotation, and arc fault labels. 8) Remove previous equipment label and apply new VA provided label.

4.3.10. 208V & 480V SWITCHBOARDS. Equipment to be inspected consists of seven (7) switchboards (EDP-1, EDP-2, 9-ECP-2, 1-MDP, 2-MDP, 2-MDP Main, MSA), but anticipate an additional two switchboards to be installed during this contract period. 1) Conduct an infrared scan of wiring compartment. 2) Check and record phase rotation at primary lugs. 3) Inspect for and report damage, missing equipment, missing labels, security to foundation, operation of doors, loose connections, malfunctioning equipment, moisture, or contamination and visually inspect ground terminations. 4) Inspect for and report damage, missing equipment, missing labels, security to foundation, operation of doors, loose connections, malfunctioning equipment, moisture, or contamination and visually inspect ground terminations. 5) Verify all switch handles are functional. 6) Test sixty-eight (68) breakers in switchboards (EDP-1, EDP-2, 9-ECP-2, 1-MDP, 2-MDP, 2-MDP Main, MSA) using breaker manufacturer’s approved secondary injection method. Manually close and trip each breaker with each of its protective devices. After testing, torque all connections to manufacture’s specifications. 7) Meters, Relays, and Instruments shall be examined and checked for calibration. Report instruments out of calibration or that have broken glass or damaged cases. 8) Indicating Lamps - Burned out lamps shall be replaced. VA will provide contractor with replacement bulbs or LED indicators. 9) Where present, verify ground fault trip mechanisms operate. 10) Verify molded case circuit breakers voltage and arc fault ratings are proper as installed. 11) Correct minor deficiencies and clean where appropriate. 12) Test ground resistance of service entrance equipment grounds and verify correct bonding. 13) Affix inspection, rotation, and arc fault labels. 14) Remove previous equipment label and apply new VA provided label.

4.3.11. PANELBOARDS. Equipment to be inspected consists of one hundred ninety-nine (199) panelboards. 1) Conduct an infrared scan of wiring compartment. 2) Check and record phase rotation at primary lugs. 3) Test ground resistance and verify proper grounding. 4) Inspect for and report damage, missing equipment, missing labels, security to foundation, operation of doors, loose connections, malfunctioning equipment, moisture, or contamination and visually inspect ground terminations. 5) Verify all breakers are functional, by turning off then back on two times, verify breakers reset, and power is restored. After testing, torque all connections to manufactures specifications. 6) Where present, verify ground fault trip mechanisms operate. 7) Verify molded case circuit breakers voltage and arc fault ratings are proper as installed. 8) Correct minor deficiencies and clean where appropriate. 9) Torque lugs if indicated by IR scan. 10) Affix inspection, rotation, and arc fault labels. 11) Remove previous equipment label and apply new VA provided label.

4.3.12. MOTOR CONTROL CENTERS. No work required for one (1) motor control center on station.

4.3.13. DRY-TYPE TRANSFORMERS. Equipment to be inspected consists of twenty-eight (28) dry type transformers. 1) Measure and record primary and secondary voltage. 2) Measure and record load current. 3) Check and record phase rotation at primary lugs. 4) Check and record ground resistance. 5) Conduct an infrared scan of wiring compartment. 6) Inspect for and report damage, missing equipment, missing labels, security to foundation, operation of doors, loose connections, malfunctioning equipment, moisture, or contamination and visually inspect ground terminations. 7) Correct minor deficiencies and clean where appropriate. 8) Torque lugs if indicated by IR scan. 9) Affix inspection, rotation, new VA provided equipment label, and arc fault labels. 10) Remove previous equipment label and apply new VA provided label.

4.3.14. BREAKER ENCLOSURES AND DISCONNECTS (FUSED AND UNFUSED). Equipment to be inspected consists of ten (10) breaker enclosures and thirteen (13) disconnects (fused and unfused).

Disconnects of 150 amps and smaller no testing or inspection is required (Facility maintenance will affix all labeling.) 1) Conduct an infrared scan of wiring compartment. 2) Inspect for and report damage, missing equipment, missing labels, security to foundation, operation of doors, loose connections, malfunctioning equipment, moisture, or contamination and visually inspect ground terminations. 3) Correct minor deficiencies and clean where appropriate. 4) Torque lugs if indicated by IR scan. 5) Affix inspection, rotation, and arc fault labels. 6) Remove previous equipment label and apply new VA provided label.

4.3.15. CAPACITORS. Equipment to be inspected consists of one (1) capacitor. 1) Conduct an infrared scan of wiring compartment. 2) Measure and record resistance to ground for each phase terminal. 3) Record and measure capacitance for each phase terminal. 4) Inspect for and report damage, missing equipment, missing labels, security to foundation, operation of doors, loose connections, malfunctioning equipment, moisture, or contamination and visually inspect ground terminations. 5) Correct minor deficiencies and clean where appropriate. 6) Torque lugs if indicated by IR scan. 7) Affix inspection, rotation, new VA provided equipment label, and arc fault labels.

4.3.16. MAIN POWER JUNCTION BOX. Equipment to be inspected consists of one (1) junction box.

1) Conduct an infrared scan of wiring compartment. 2) Inspect for and report damage, security to foundation, loose connections, malfunctioning equipment, moisture, or contamination and visually inspect ground terminations. 3) Correct minor deficiencies and clean where appropriate. 4) Torque lugs if indicated by IR scan. 5) Affix inspection and arc fault labels.

4.3.17. GROUND RESISTANCE ANALYSIS. A concise qualitative description (not to exceed one (1) page of narrative) describing the overall condition of the facility ground resistance shall be provided. Any violations of NEC or other abnormalities (high ground resistance, damaged conductors or electrodes, harmonics, etc.) warranting further detailed study shall be highlighted. Analysis of the facility ground resistance shall be based upon 1) visual inspection of visible ground system components (made during site investigation). Include photographs in Appendices. 2) testing and documenting of the grounding systems as installed. 3) other data on ground system made available by FMS.

4.3.18. Short Circuit Study. 1) Systematically calculate the fault impedance to determine the available short circuit and ground fault currents at each bus. Incorporate the motor contribution in determining the momentary and interrupting ratings of the protective devices. Motors less than 25-hp may be grouped together. 2) Use actual conductor impedances if known. If unknown, use typical conductor impedances based on IEEE Standard 141-1993 - IEEE Recommended Practice for Electrical Power Distribution for Industrial Plants. 3) Transformer design impedances shall be used when test impedances are not available. 4) Provide the following: calculation methods and assumptions, selected base per unit quantities, one-line diagram of the system being evaluated, source impedance data, including electric utility system and motor fault contribution characteristics, tabulations of calculated quantities, and results, conclusions, and recommendations. 5) Calculate short-circuit momentary and interrupting duties for a three-phase bolted fault at each: electric utility’s supply termination point, incoming switchgear, unit substation primary and secondary terminals, low voltage switchgear, ATSs, branch circuit panelboards, and other significant locations throughout the system. 6) For grounded systems, provide a bolted line-to-ground fault current study for areas as defined for the three-phase bolted fault short-circuit study. 7) For protective device evaluation: evaluate equipment and protective devices and compare to short circuit ratings, adequacy of switchgear, motor control centers, and panelboard bus bars to withstand short-circuit stresses, and notify owner in writing, of existing, circuit protective devices improperly rated for the calculated available fault current.

4.3.19. ARC-FLASH HAZARD ANALYSIS. 1) The arc-flash hazard analysis shall be performed according to IEE Standard 1584-2018 - IEEE Guide for Performing Arc-Flash Hazard Calculations, equations that are presented in NFPA70E-2024, Annex D. 2) The flash protection boundary and the incident energy shall be calculated at all equipment locations identified in the previous study (2014) as well as equipment placed into service since the previous study. 3) The arc flash hazard analysis shall include all significant locations in 480-volt and 208-volt systems regardless of transformer size. 4) Safe working distances shall be based upon the calculated arc flash boundary considering an incident energy of 1.2 Cal/cm2. 5) When appropriate, the short circuit calculations and the clearing times of the phase overcurrent devices will be retrieved from the short circuit and coordination study model. Ground overcurrent relays should not be taken into consideration when determining the clearing time when performing incident energy calculations. 6) The short circuit calculations and the corresponding incident energy calculations for multiple system scenarios must be compared and the greatest incident energy must be uniquely reported for each equipment location. Calculations must be performed to represent the maximum and minimum contributions of fault current magnitude for all normal and emergency operating conditions. The minimum calculation will assume that the utility contribution is at a minimum and will assume a minimum motor contribution (all motors off). Conversely, the maximum calculation will assume a maximum contribution from the utility and will assume the maximum number of motors to bet operating. Calculations shall take into consideration the parallel operation of synchronous generators with the electric utility, where applicable. 7) The incident energy calculations must consider the accumulation of energy over time when performing arc-flash calculations on buses with multiple sources. Iterative calculations must consider the changing current contributions, as the sources are interrupted or decremented with time. Fault contribution from motors and generators should be decremented as follows: fault contribution from induction motors should not be considered beyond 3 to 5 cycles and fault contribution from synchronous motors and generators should be decayed to match the actual decrement of each as closely as possible (e.g., contributions from permanent magnet generators will typically decay from 10 per unit to 3 per unit after 10 cycles. 8) For each equipment location with a separately enclosed main device (where there is adequate separation between the line side terminals of the main protective device and the work location), calculations for incident energy and flash protection boundary shall include both the line and load side of the main breaker. 9) When performing incident energy calculations on the line side of a main breaker (as required above), the line side and load side contributions must be included in the fault calculation. 10) Miscoordination should be checked amongst all devices within the branch containing the immediate protective device upstream of the calculation location and the calculation should utilize the fastest device to compute the incident energy for the corresponding location. 11) Arc-flash calculations shall be based on actual overcurrent protective device clearing time. Maximum clearing time will be capped at 2 seconds based on IEEE Standard 1584-2018 section B.1.2. Where it is not physically possible to move outside of the flash protection boundary in less than 2 seconds during an arc-flash event, a maximum clearing time based on the specific location shall be utilized.

4.3.20. ARC FLASH LABELING. 1) Produce and deliver to the Grand Junction campus up to five hundred (500) arc flash warning labels in accordance with NFPA 70 and NFPA 70E. Interior labels shall be 4-inches by 6-inches (nominal) printed on industrial quality, adhesive backed vinyl. Exterior labels shall be 4 inches by 6 inches (nominal) engraved plastic sheet. “Danger” labels shall have pre-printed headers in red; “Warning” labels shall have pre-printed headers in orange. Electrical equipment shall be labeled IAW NFPA 70, Article 110.16 and NFPA70E, Article 130.5 (C). The arc-flash hazard analysis to determine the arc-flash protection boundary for each label shall be calculated IAW NFPA 70E Paragraph 130.5 (A). For each device for which a hazardous analysis is conducted, the equipment shall be field marked with a label containing the available incident energy or required level of PPE. 2) In addition to the requirements of NFPA 70 and 70E, each customized label containing specific available incident energy or required level of PPE and shall identify the corresponding piece of electrical equipment, by panelboard or device identifier and building number. The identification shall be in a manner understood by Grand Junction facility personnel who will be applying the labels to the respective devices. Generic labels do not require equipment and building identifiers.

· For each applicable 480-volt, and 208-volt panelboard, one arc-flash label shall be provided.

· For each low-voltage switchboard, one arc-flash label shall be provided.

· For each switchgear, one arc-flash label shall be provided.

· For medium voltage switches one arc-flash label shall be provided.

· For each machine control panel, one arc-flash label shall be provided.

· For each transformer, one primary and one secondary arc-flash label shall be provided.

· For each disconnect, one arc-flash label shall be provided.

4.3.21. PROTECTIVE DEVICE COORDINATION STUDY. 1) Prepare the coordination curves to determine the required settings of protective devices to ensure selective coordination. Graphically illustrate (using logarithmic scale) that adequate time separation exists between series devices, including the utility company upstream device. Plot the specific Time Current Characteristics (TCC) of each device in the electrical system as follows: (a) Provide TCC curve down to the last branch-circuit panelboard (regardless the protective device is an adjustable or fixed device) in the three-branches of the EES. (b) Provide TCC curve down to the last adjustable device (stop after the first fixed device) in the Normal System but at the minimum two-level curves from each of the building Service Entrance switchgear/switchboard shall be provided. 2) The following specific information shall also be shown on the coordination curves at each level of power distribution system: (a) Device identification (including manufacturer, catalog number, and device curve number and ID). (b) Voltage and current ratio for curves. (c) Three-phase and single-phase ANSI damage points for each transformer. (d) No damage, melting, and clearing curves for fuses. (e) Cable damage curves. (f) Transformer inrush points. (g) Maximum short circuit cutoff point. (h) Excerpts from one-line diagram reflecting the protective devices modeled on each curve. This excerpt may be inserted onto a corner (typically top right-hand) of the curve print out or may be on the preceding facing page for ease of reference. (i) Provide explanation, analysis, and recommendation to achieve better coordination. (j) The analysis for recommended curve of a device (either adjustments to the existing device or a recommended replacement device) shall be put right after the existing curve in the report for comparison. 3) Develop a table to summarize the settings selected for the protective devices. Include all medium voltage devices in the table, as well as all low voltage devices which require modification, showing the following data: (a) Device identification. (b) Relay CT ratios, tap, time dial, and instantaneous pickup. (c) Circuit breaker sensor rating, long time, short time, and instantaneous settings, and time bands. (d) Fuse rating and type. (e) Ground fault pickup and time delay.

4.4. Deliverables for CLIN 0003

4.4.1. INTEGRATED BASELINE REVIEW (IBR). 1) Upon completion of the study and prior to the end of performance period, the Contractor will conduct an Integrated Baseline Review (IBR) meeting with the Grand Junction Engineering staff. The IBR is intended to allow the lead Engineer of the Contractor’s team the opportunity to provide the Owners (i.e., Chief Engineer, Grand Junction facility personnel) a mutual understanding of the risks inherent with deficiencies found and the potential consequences if such deficiencies are not corrected. The Contractor Engineer shall review the findings of the study with the Grand Junction staff and explain inherent risks and respond to any questions regarding the study. Properly conducted, this IBR shall foster the development of a Risk Management Plan and garner support for correction of critical deficiencies. At the conclusion of the IBR the Contractor Engineer shall obtain signatures from the Chief Engineer indicating they have received the study and have been apprised by the Contractor of the associated risks. 2) For all electrical equipment, determine if adequate code clearances exist. Note cases by location and specific equipment that do not include adequate code clearances and provide a cost estimate to resolve the problems.