S06 - p. 2 of SF30 - Responses to RFIs.pdf

SF 30 Continuation Page 36C252-20-B-0025 676-14-105 Replace Boilers B415 Tomah VAMC

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Amendment A0004

1. Public Bid Opening is scheduled for Tuesday, October 6, 2020 at 2:00pm CT.

Attendees are required to wear a face mask.

2. Please note a revised Bid Schedule & Phasing Plan will be issued in a follow-up Amendment.

3. Questions (Q) & Responses (R):

Q3: PCG (designer) missed an isolation valve on the inlet to the DA. The VA requires one here for safety device testing of the LPS safety valve, but the VA Standard Details also miss it. You have to isolate this valve, crack the PRV bypass to see the pressure that the LPS safety lifts at. The only way to do that is to isolate at the DA inlet and pressurize the LPS line with more than 5#. PCG shows a steam control valve in this location, but that’s not correct. The control valve is the Spence Pressure Reducing Valve in the PRV station.

R3: The low-pressure steam valve in the inlet to the DA Tank dome is a manual shut-off valve, as noted in the RFI. The control head was added to the valve inadvertently and is not required.

Q17: Reference Specification 01 35 26; Can the Prime Contractors Site Superintendent also fulfil the duties of SSHO?

R17: This can be the same person – However, this person cannot be the CQC System Manager

Q18: Reference Specification 01 35 26-16; Just confirming that a CSP or CSHT will be required to make monthly inspections of the project site throughout the duration of the contract?

R18: 01 35 26 - 16, 1.9 INSPECTIONS: The SSHO shall conduct frequent and regular safety inspections (daily) of the site and each of the subcontractors CPs shall conduct frequent and regular safety inspections (daily) of the their work operations as required by 29 CFR 1926.20(b)(2). Each week, the SSHO shall conduct a formal documented inspection of the entire construction areas with the subcontractors’ “Trade Safety and Health CPs” present in their work areas. Coordinate with, and report findings and corrective actions weekly to Contracting Officer Representative.

Q19: Reference Specification 01 45 00-5; Can the CQC System Manager also fulfill the duties of SSHO?

R19: This can be the same person - However this person cannot be the Prime Contractors Site Superintendent

Q20: Is it required that the SSHO, CQC be direct employee(s) of the Prime Contractor?

R20: Yes, see Section 01 45 00 Quality Control, 3.4 (b) Quality Control Organization: This CQC System manager is on the site at all times during construction and is employed by the General Contractor.

Q27: Please confirm site utilities may be used for watering during the repair of any damaged lawn and re-sodding.

R27: Yes, use of VA hose bibs is acceptable. Contractor must supply their own equipment.

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Q30: In Reference to Burner: Can you confirm that the fuel used for this job is natural gas/LP gas or natural gas/LP-air mixture? This would make a big difference on whether we quote 1 or 2 gas trains with each burner. The schedule just says natural gas and propane, but the drawings show a single gas train per burner.

R30 REVISED: Natural gas at (burner required) psi or LPG at (half of natural gas pressure) psi.

Q37: Drawing set #3 was published as a 8 ½ x 11. Can the VA reissue the set #3, to the 42x30 page size.

R37: Drawing Set #3 attached which will print 30” x 42”.

Q41: 230811, page 5, 3.6, E. Do not exceed three trainees per session, one four-hour session, per day per trainee. Line A, the contractor owes 16 instructor hours. Does this mean this must be spread out over a 4-day period? The Boiler Manufacturers are charging $ 3800 per day. To quantify pre bid, how many trainees will the contractor have to train? Based on lines A, B, C, &D (36 hours total), there will be 9 total days required by the VA for testing assuming that there will be no more than 3 VA trainees. As it stands, if we are to assume only 3, the total dollar could be more than $34,200 for every group of 3, if the VA adds one or more trainees the fee could double to $68,400.

R41: The VA has seven (7) employees that will need this training. The VA also requires this training to be video recorded for refresher training and for record.

Q54: 23 22 13 Steam and Condensate Piping: This section differs from section 23 21 11 Boiler Plant Piping. Clarify which section to use or clarify differences. Example: Vent piping is carbon steel in one and Galvanized in the other.

R54: Any vent from a tank, safety or relief valve requires carbon steel ASTM A53 pipe, per 22 21

11. Per 23 22 13 - other vents may be steel ASTM A53 or ASTM A106 sch 40 galvanized.

Q55: 23 50 11 Boiler Plant Equipment:

a. 2.2.M Water Level Indicator: ‘Jerguson Liquid Level Gage, Magnicator 2’ in lieu of site glass. Won’t break and can be serviced without taking DA system offline. Fully electronic switches and transmitter in NEMA 4X enclosure.

b. 2.2.N & M Low- and High-Level switches: ‘Wave guided Radar by Rosemount’ in lieu of float or probe type switches. More reliable and does not scale up and give faulty signals. Fully electronic 4 – 20 mA signal to PLC controls.

c. 2.3 Condensate Storage Tank: Paragraph ‘C’ and ‘G’ states carbon steel tank with epoxy liner. Request using 304 stainless steel in lieu of carbon/epoxy liner to extend life of tank. Epoxy liners are subject to failure on a single pin hole, epoxy liners are subject to minimal temperatures. If cond tank is used to back up DA higher temp water and possible steam flashing would be higher than epoxy temperature rating.

d. 2.2.I Water Level Indicator: ‘Jerguson Liquid Level Gage, Magnicator 2’ in lieu of site glass. Won’t break and can be serviced without taking DA system off line. Fully electronic switches and transmitter in NEMA 4X enclosure.

e. 2.2.J Low- and High-Level switches: ‘Wave guided Radar by Rosemount’ in lieu of float or probe type switches. More reliable and does not scale up and give faulty signals. Fully electronic 4 – 20 mA signal to PLC controls.

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R55: Until the actual boiler is determined, some of these questions cannot be answered. Therefore, substitutions can be verified only after award of project. In addition, note that the VA guides may limit some technology and styles of switches, gages, etc.

Q60: Who is responsible for removing the JCI control panels?

R60: Bidding contractor to determine - GC, Mean and Methods

Q61: Will the plant carbon monoxide and gas detection be provided by JCI?

R61: Bidding contractor to determine - GC, Mean and Methods

Q66: For Temporary Boiler to be considered for meeting N+1 Requirements, it must be capable of operating on a Backup Fuel (other than Natural Gas.) If Boiler is equipped with Number 2 Fuel Oil backup fuel, a quantity of fuel oil must be kept on-site to meet the requirements in 1810(1) page 6, Section 5. c. (7)- or at least that portion of the requirements as pertains to the Temporary Boiler. If Temporary Boiler is Not to have fuel oil backup, it must be capable of utilizing the on-site Propane system, and connected to that system.

R66: Provide 4" LP connection with isolation valve on end of main and run down to underneath cat walk through exterior wall and tie into temp 4" NG piping with local isolation valve.

Q67: Ensure that "Commissioning" of new Boilers includes thorough testing of All Directive and 5th Edition Manual required Safety Devices. Boilers Not To Be Accepted Until and Unless All required Safety Devices (Boiler and Plant) are fully compliant with VHA Requirements.

R67: VHA testing requirement is references in specification 230510 Common Work Results for Boiler Plant and Steam Generation. Reference will be added to M001 General Notes in future amendment.

Q73: Clarification Required: See below for the alternate description in the bid schedule documents, after reviewing the phasing plans the boiler # do not match up with the description below. The phasing plan stats (GC108) phase 3 is to de-energize boilers 1 & 2.

R73: A revised Bid Schedule and Phasing Plan will be issued in follow-up amendment.

Q74: Regarding the existing Metasys ECC manufactured by Johnson Controls Inc. Section 23 09 23 Part

1.1 – F, refers to the existing system and mentions that the system shall “observe the capabilities, communication network, services, spare capacity of the existing control system and its ECC prior to beginning work.” This would indicate that the existing system should be used. Subsection 1 calls to “Remove existing direct-digital control system ECC… Replace with new BACnet ECC.” This is a massive undertaking since the existing ECC is connected to hundreds of controllers on site. This would require, mapping and graphics etc for the whole system which seems to go well beyond the scope of this project which is to replace boilers. Is a new ECC required or can the existing ECC be utilized to keep costs down?

R74: Removal and replacement is within Building 415, not the entire campus.

Q75: 23 09 23 also mentions a “control system integrator” that is to contract directly to the GC. Is there a separate “control system integrator” for this project?

R75: No

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Q76: Section 23 09 23 Part 1.1 – D – 7, refers to having limited control of the “Building lighting systems” R76: Remove

Q77: What scope if any is required associated with the lighting for the BAS? How many points? Is scene control setup by the BAS or others? Is an integration required? If so what lighting system is being used?

R77: Not required

Q78: Page 23 09 23-22 of the specification also mentions that a server should be provided as part of this job. If we do extend the existing JCI system this is not needed since we have an existing server. Is a separate server required for this job or can 23 09 23 2.2,E be removed? 23 09 23 Part 2.4 on page 23 09 23-24 also mentions a new ECC that is a B-AWS? Is a B-AWS required for this job? The existing JCI system is not a B-AWS and this would be a very large additional amount of labor and money and would not be an extension of the existing JCI system so this connects to the first RFI above.

R78: Remove

Q79: On page 23 09 23-26 a dot matrix printer is mentioned. Is this required for this project?

R79: Remove

Q80: On page 23 09 23 – 32 there is a section referring to “Electrical, Gas, and Weather Reports.” Is this required as part of this project? If so what meters are being connected to? An integration to a weather service would be required. Is that integration desired?

R80: Boiler Building 415 has existing electric and gas meters that provide the reports as noted. Connect to the existing meters. Connect to a VA approved weather service.

Q81: 23 09 23 – Part 2.5 calls for a “Portable Operator’s Terminal.” Is this desired as part of this project?

R81: Yes

Q82: 23 09 23 – Part 2.6 talks about a “bacnet protocol analyzer” this seems outside the scope of this project. Is one required for this project?

R82: Remove

Q83: Please provide information on the existing switchgear(Main Distribution Panel) located in the room

(108) next to the generator? Please provide breaker numbers or switchgear model number to get the new panels DP1 & LP1.

R83: see photo below

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……..End of Amendment A0003……..