A0003 - p. 2 of Amendment 3.pdf

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

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Amendment A0003

1. Bid Opening has been extended to Tuesday, October 6, 2020 at 2:00pm CT.

2. The following is incorporated into the solicitation: Compliance with VHA Directive

1192.01 VHA Directive 1192.01 issued August 10, 2020 requires all contractor personnel to receive annual seasonal influenza vaccinations or obtain an exemption for medical or religious reasons. Compliance with this directive is a requirement of this contract. A copy of VHA Directive 1192.01 is available at this link and is an attachment to this amendment:

https://www.google.com/url?sa=t&rct=j&q=&esrc=s&source=web&cd=&ved=2ahUKE wi0t7CAj_DrAhXDgnIEHbVSCwgQFjAAegQIBRAB&url=https%3A%2F%2Fwww.va .gov%2Fvhapublications%2FViewPublication.asp%3Fpub_ID%3D8948&usg=AOvVaw 1Rwijbc9Z5WL5ilsgWoagN”

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

Q1: Which tank is considered to be asbestos containing? Both large DA tanks are shown on the survey to be non-Asbestos.

R1: Per the ACM Spreadsheet Inventory found in spec section 02 82 13.14, the "Condensate Tank blk" contains 375 SF of friable material. Various pipe fittings at the Condensate Tank contain friable material as well.

Q2: What is expected for the lead paint abatement? Full 100% removal of all designated lead based paint.

Or removal of all loose, peeling, and flaking lead based paint?

R2: 100% removal.

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. Correction will be issued.

Q4: Will we have full access to the building during abatement? No civilian staff?

R4: Per VA requirements, Plant must remain staffed 100% of the time.

Q5: Can we perform the abatement and LBP at the same time, or do we have to perform each scope separately?

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R5: Can be performed at the same time.

Q6: How clean of a surface will we need to leave it after LBP is performed? Are we supposed to stabilize the LBP (just loose flaking paint) and prime it afterwards or are we required to remove all lead paint throughout?

R6: 100% removal.

Q7: What kind of sampling will be required for the LBP? Wet wipes or visual inspection?

R7: Paragraph 3.7.C indicates testing of LBP is required where indicated and when directed by COR, and according to 40 CFR Part 261. CIH Certification requires that no visible accumulations of LBP and dust remain at worksite, per paragraph 3.7.B.

Q8: Will everything be shut down and deenergized prior to arrival?

R8: The plant will remain operational.

Q9: Are both tanks on the condensate platform getting abated? Spec says 375 SF total insulation to be removed. Tank SF is much larger than what was indicated on drawing.

R9: Although the 2019 survey states that no asbestos was detected at the "Insulation jacket core condensate tank", an earlier survey (undated) notes 375 SF of "Condensate Tank blk", referring to block pipe insulation supports. Both surveys are included in the specifications.

Q10: Will we have to provide our own 3rd party monitoring consultant, or will the VA be providing it?

R10: Per the specifications, the Certified Industrial Hygienist (CIH) is employed by the Contractor (paragraph 1.3.D) and responsible for the tasks listed in paragraph 1.7.D, including monitoring

Q11: Abatement and LBP is supposed to be completed during Phase 1 work, how many shifts will abatement contractor have to complete scope of work?

R11: Abatement and LBP abatement can be any shift, 24/7.

Q12: It shows panel LP1 being fed out of Panel DP1 and DP1 is 480/277volt and LP1 is shown as 208Y/120volt. Is a transformer needed or is Panel LP1 supposed to be 480/277volt?

R12: The text in Detail 2 on Sheet E601, key note 5 is a drawing typo. The one-line diagram is correct.

The panel will serve the existing lighting and shall be a 480Y/277V, 3PH, 4 Wire panelboard and should be directly fed from DP-1.

Q13: Please confirm bids will be accepted by email.

R13: Bids will not be accepted by email.

Q14: Will there be a virtual bid opening available for contractors to attend?

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R14: Bid Opening will be held in person at the Great Lakes Acquisition Office (GLAC) office 115 S. 84th Street, Suite 101, Milwaukee, Wisconsin 53214. See SF 1442, Block 8. Wearing of a face mask is required.

Q15: Will a scanned copy of bid bonds be acceptable?

R15: Yes, scanned copies of the bid bond will be acceptable, in accordance with the Class Deviation issued May 11, 2020, in response to the COVID-19 national emergency, as authorized by the Civilian Agency Acquisition Council (CAAC) letter 2020-04, dated May 1, 2020.

Q16: Is this project Tax Exempt?

R16: No, this project is not tax exempt.

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

R17: Response to be provided in future amendment.

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: Response to be provided in future amendment.

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

R19: Response to be provided in future amendment.

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

R20: Response to be provided in future amendment.

Q21: Please confirm the VA will be providing a 3rd party independent commissioning agent for this project and will be responsible for those associated costs.

R21: Per 01 91 00, 1.2 CONTRACTUAL RELATIONSHIPS, the VA will contract with a 3rd party, independent commissioning agent and is responsible for those costs. The contractor is responsible for the execution of the commissioning process.

Q22: Should there be a discrepancy between the drawings and the specifications, which document shall supersede?

R22: In accordance with FAR Part 52.236-21, in case of difference between drawings and specifications, the specifications shall govern.

Q23: Will the concrete equipment pad that is built for the temporary boiler remain in place after project completion? Or are we to remove and re-sod?

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R23: Leave in place.

Q24: Drawing HL101 provides locations of lead paint but does not provide much detail to quantity.

General note 1 and 2 mention a lead paint abatement report providing room by room information. Will contracting please provide this report?

R24: 100% removal; report is in the specifications.

Q25: HA101 general notes 1 and 2 mention an ACM report providing room by room information. Will contracting please provide this report?

R25: 100% removal; report is in the specifications.

Q26: Drawing A001 Note 10 is requiring erection of a dust barrier with HEPA ventilation and maintaining a negative air pressure within the space throughout construction. This is understandable in working in or around hospital operations. However, given that this powerhouse is far away from medical operations at the back of the property, is general dust control and management sufficient without the requirement of full encapsulation and negative air pressure?

R26: This requirement is if you are venting to within the building. The same note states if venting to the outside, then negative air and dust control must be provided.

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

R27: Response to be provided in future amendment.

Q28: Specification section 05 12 00 1.4G has a statement for “Delegated Design Drawings and Calculations”. Please confirm this is not required for areas where existing steel is being removed and reinstalled.

R28: Not required

Q29: Specification section 05 12 00 1.4G has a statement for “Delegated Design Drawings and Calculations”. Is this specific to the access platform and ladder at each boiler? If using prefabricated solution, will manufacturer specification sheets suffice?

R29: Including roof openings and caps, access and platform at each boiler, modifications required for existing platforms. Existing platforms at boilers include manufacturer’s specifications.

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: Natural gas at 30 psi or LPG at 15 psi.

Q31: In reference to Controls: Drawing page M702 and Section 01 91 00 - Pg.13 and 23 09 23 - Pg 12&13 there is a BAS (Building Automation System) referenced. Section 23 09 23 Direct-Digital

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Control is referenced. Section 23 09 11 - Pg 11 2.1 D.3.c. and Pg. 38 2.5 C. and Pg.62 2.15 b.3.

Supervisory Control and Data Acquisition (SCADA) is referenced.

a. Is the BAS and the DDC the same system? Or is the BAS a different system such as a balance of plant control system? Dwg M-702 also mentions a local controller. Is this the BAS or a local DDC controller, or a balance of plant controller?

b. Dwg M-702 shows some signals connected to a local controller and some connected to the BAS. If there is not a balance of plant controller, and the BAS is the same system as the DDC, some signals would need to be sent from the DDC to the workstation for display, monitoring, and trending. Please provide more explanation regarding the required architecture between BAS, DDC, the workstation, and the boilers.

R31: The BAS and DDC are the same. The boiler system has its own independent control system which the BAS will monitor only.

Q32: In Reference to Deaerator: What size tank do you need on the DA? The schedule appears to be wrong and lists a spraymaster from CB that's 4500 gallons. The specs say feedwater at a max of 30k pph.

Can you confirm the CB model actually has the listed storage capacity or if we need to meet that? Lastly, we believe this is supposed to be a tray type DA but the model is a spray type.

R32: The basis of design is CB for reference only. Size and type depends on manufacturer selected/approved.

Q33: The pumps on the schedule doesn't hit any curve at all. CRI 5 is not large enough to handle the generic sizing requirements. If you base this on 900 BHP, safety valve set at 130 psi, you get a CR 32 and that's not including the added flow for being on a mezzanine and recirc.

R33: Provide pumps to meet the requirements listed on the drawings and in the specifications.

Q34: Are we allowed to have the VFD's be integral to the pumps?

R34: No, separate.

Q35: M601 - Blowdown Separator is called out in the schedule but a blowdown tank referenced everywhere else; Please confirm the intent is to receive one blowdown separator sized for the three new boilers.

R35: Provide a blowdown separator per plan and specifications. Contractor can provide an alternate of a blowdown tank after award.

Q36: On pg. 355 - boiler blowoff piping - 2.5 F it states that at no point shall the bottom blow down lines rise above the point of connection to the boiler. We are unsure if this is practical and wanted to make sure you did not mean the continuous blowdown line should not rise above the drum connection point.

Depending on where the blowdown lines are run and where the blowdown separator is located you would likely need to elevate the piping.

R36: Both blowdown lines are in a trench and the blowdown separator in a basement area.

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: Response to be provided in future amendment.

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Q38: Given the weight of the temporary boiler and the location in proximity to the boiler plant. Will cribbing be required.

R38: Means and methods.

Q39: Does the VA have an existing underground utility map for the contractor, or will the VA locate all existing utilities?

R39: Shown on drawing GC110. General contractor to verify.

Q40: On drawing GC108, the drawing indicates a 6” HPS connection to the temporary boiler. However, on MP 101 shows a 4”. Please confirm the correct size.

R40: 6" HPS should be provided.

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: Response to be provided in future amendment.

Q42: Temporary Boiler Plant Installation:

a. Paragraph ‘A’ states, ‘Temporary facilities must remain in operation until all new facilities are accepted for beneficial use’. When does Temp boiler need to be on site and connected. Phase 1 has all three existing boilers in service so no need for temp boiler. Phase 2 when boilers 2 and 3 are off line for replacement, Boiler 1 (20,000 lb/hr) and Temp boiler would be needed for N+1. After Phase 2 is complete and Phase 3 starts, B2 and B3 boilers are on line so one boiler can back up the other N+1 if load is below 30,000 lb/hr. No need for temp boiler. Clarify what the peak steam loads are for the months of each phase to determine what is N+1 and when temp boiler is needed.

b. Paragraph ‘A’ states, ‘Temporary facilities shall provide the same quality and capacity of service as existing facilities’. Would there be an option to use two rental boilers based on peak load N+1 with control room trailer and do all three phases of construction at one time. Could reduce time frame and possible cost. Please clarify if this is an acceptable option for bidding.

c. Paragraph ‘A’ states, ‘Temporary facilities shall provide the same quality and capacity of service as existing facilities’. What is the Temporary boiler size in steam capacity during each month to determine size? Need to know for N+1.

d. Paragraph ‘O’ states, ‘Fuel Oil system shall operate with no air entrainment or pump cavitation’. No oil is specified else ware in the spec or drawings. Please clarify.

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e. Paragraph ‘R’ states, ‘Provisions shall be made for operators control room within line of site and adjacent to the temporary equipment to allow 24/7 oversight of system. This will include appropriate break and restroom facilities’. This operations trailer is not shown on drawings anywhere. The existing plant will be in service and operator control room in use during construction. Do we need to provide a Boiler Operator control trailer? Please clarify. Would a remove monitoring/alarm panel acceptable for the temp trailer in the existing control room.

f. Paragraph ‘T’ states, ‘Provide materials and thickness as specified for permanent installation’ Temp boiler stacks extensions are field installed and typically not insulated do to temporary use only. Please clarify if needed and if so up to what elevation above grade outside.

g. Sample coolers for Temp boiler is not listed. Will one be required?

h. Paragraph ‘G.9’ states, ‘Equipment with all safety devices defined and tested in accordance with the VHA Boiler Plant Safety Device Testing Manual at the contractor’s expense’. Rental boiler suppliers throughout the nation do not make a temp boiler system that meets all the requirements of BEI. Some items can be retrofitted such as some switches and gauges but some are not possible do to some items due to Boiler supplier will not allow any modifications to any pressure parts, burner or controls. Please clarify what is the minimum safety requirements for the temp boilers that are available from the suppliers.

R42: Response to a: N+1 has to be met at all times. The duration of the temp boiler operation is a means and methods.

Response to b: Contractor should bid per plan and specification. However, alternate methods can only be approved after award.

Response to c: Capacity to match 30000 lb/hr.

Response to d: Omit reference to Fuel Oil.

Response to e: The intent is for the existing operating control room to have line of sight and direct access to temporary boiler trailer. Omit restroom provisions.

Response to f: The stack should be installed to meet VA and code requirements for elevation.

Response to g: Yes, sample cooler should be provided if existing cannot be used.

Response to h: Provisions shall be accommodated by means approved by VA.

Q43: Please clarify Phase 1 work of how Deaerator and Condensate tanks and associated pumps and piping is being used during uninterrupted service to the plant. Drawings and specifications do not indicate temp pumps, valving, means of removal or staging. Size of condensate tank pumps are not capable of using as temporary pumps for boiler feed if DA system is being worked on.

R43: New pumps installed adjacent to existing before existing pump demolition for all pumps.

Q44: 23 05 10- 1.8 C. Steam and Condensate service interruptions: Please clarify that there will need to be multiple outages for valve replacements during all three phases throughout the year for tie-into existing, capping, phasing of equipment, etc. throughout the project. Spec states only during non-heating season and non-critical periods and limited to 8 pm to 5am. Clarification is needed to how to do tie-ins for phases over the heating seasons.

R44: Coordinate all shut-downs during non-heating season and as scheduled by VA.

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Q45: 23 05 10 2.7 Please clarify if Bypass switches are required on VFDs. Individual sections do not identify. Bypass is needed for burner fans for testing and commissioning. Pump VFDs may or may not need bypasses. Clarify.

R45: Bypass - see 262911.

Q46: 23 07 11 - Paragraph A.2 request substitute of mineral fiber insulation in lieu of Calcium Silicate and paragraph 2.c use all aluminum jacketing in lieu of PVC since PVC will melt on any high temperature system at joints and near valves.

R46: Contractor shall provide per specifications.

Q47: 23 07 11 – 3.6 Question Paragraph A.3 request using Mineral fiber insulation with aluminum jacketing in lieu of Calcium Silicate and glass cloth.

R47: Contractor shall provide per specifications.

Q48: Sheet MD103 Mechanical Upper Mezzanine Plan – Demolition: Scale on drawing doesn’t match ¼” scale. Appears to be 1/8” scale.

R48: Drawing scale is 1/4" = 1'-0"

Q49: Sheet MP101:

a. Key Note #25 does not indicate if heat tracing is required on temp piping. If temp boiler is only during Phase 2 work during the summer of 2021 none is required. If temp boiler will be on during Phase 1 or 3 during winter months who is providing it. Please clarify if needed and by who.

b. Where does 6” drain (bottom blow down line) on back (Right side) of the boiler get extended to for disposal of water.

R49: Response to a: Temporary boiler used during non-heating season. Changes by contractor at contractor’s cost. Response to b: Nearest drain.

Q50: Sheet M601 Mechanical Schedules: HVAC Motor Schedule does not indicate motors for the MAU- 1 and ACCU-1. Are these powered from other source?

R50: See electrical power plans and schedules.

Q51: Sheet M602 Mechanical Schedules: Steam Pressure reducing Station Schedule only indicates two new PRV’s for PRV-10 and PRV-10A. Are remaining PRV’s staying. Sheet MD401M304/Section B indicate something on these PRV’s to be done, partially dashed and connect to symbol. Please clarify scope.

R51: All pneumatic controllers replaced with electric. Noted on plans, diagrams and phasing.

Q52: 23 21 11-2.13 Valves: Clarify valve flange spec. Paragraph ‘D above 15 psig pressure and all valves on PRV stations’ 2-1/2” and larger “HPS and MPS” are listed as ‘Type 101 and 201’ are 150 psi flanges.

All other flanges on condensate, condensate transfer, feedwater suction, boiler feed, overflows, control and instrumentation piping systems are all 300 psi flanges. Please clarify if this is correct. Low pressure systems usually have 150 psi flanges and High or medium pressure systems are 300?

R52: Low 150 psig, medium and high 300 psig.

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Q53: 23 21 11-3.3 Welding: Item ‘H’ Non-Destructive Examination of piping Welds. X-Ray machines within the boiler room will knock out any boiler which is operating due to Flame scanner UV sensor. This has been a ongoing problem at many facilities around the country. Please clarify if this will be acceptable to the owner since it will disrupt steam production throughout construction.

R53: No disruption of service.

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: Response to be provided in future amendment.

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.

R55: Response to be provided in future amendment.

Q56: Are Allen Bradley PLC’s acceptable for the Combustion Controls for each boiler and Balance of Plant controls?

R56: PLC must meet boiler and VA specification requirements.

Q57: In order to save space would it be acceptable to put both the Combustion Controls and the BMS in the same enclosure? The required wiring between the two systems would then be complete inside the panel. We would then include the VHA testing panel right there too.

R57: Must meet boiler and VA specification requirements.

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Q58: Is it acceptable for the controls enclosures to be NEMA 12?

R58: Must meet specification requirements.

Q59: Can you please explain the operation of the four modulating control valves for the feedwater control around the economizer; economizer inlet, economizer outlet, economizer bypass and then the feedwater control valve into the boiler. What is the anticipated operation? Should they all be modulating? Or slow open / close?

R59: Maintain highest efficiency for boiler and maintain flue gas temp from economizer. Valves shall be modulating type.

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

R60: Bidding contractor to determine

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

R61: Bidding contractor to determine

Q62: For the stack sensors mentioned; CO2, N2, H2O, O2, SO2, typically the only permanent emission sensor is the O2 which is used for oxygen trim on each boiler. There is a port on the stack for connecting a test probe during the emission tests. If permanent sensors for constant monitoring is required beyond the O2 sensor this adds quite a bit of cost to the project. This also includes opacity. Opacity monitoring was typically used for boilers burning coal in the past. Is the opacity meter required? Are the sensors the CO2, N2, H2O and SO2 all required as permanent sensors constantly monitoring?

R62: Opacity not required. CO2, N2, H2O and SO2 not permanent sensors.

Q63: Please confirm which motors require VFDs for the pumps and fans, including the makeup air units.

Starters are mentioned and so are VFDs for some.

R63: See electrical power plans and schedules.

Q64: The D/A Overflow should be routed to a safe drain- NOT tied to the Condensate Storage Tank (CST) system Piping. To do so would move the CST vessel requirements into the same design/testing/maintenance category as the Deaerator Vessel. See also Sheet M503 at F8.

R64: DA Tank drain should be separate from Condensate Tank as per the mechanical drawings. Overall diagram and Keyed Note 21 on GC105 shall be modified to be posted in future amendment.

Q65: Provide a flow switch based alarm in the combustion air supply air handler.

R65: Flow switch should be added to 415-HV-1 and 415-MAU-1, see sheet M701.

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

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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.

Q68: 24-inches may not be adequate for clearance of snow accumulation- check local climatic projections for snow accumulation/ snow loading.

R68: Omit 24" dimension from architectural detail 9/A501.

Q69: VA Standard Detail SD230541-03 calls out minimum Housekeeping Pad Thickness as 5-inches-drawing notes pad thickness of 4-inches.

R69: Revise detail 8/A501 to be 5" thick.

Q70: Drawing indicates drains from both valves (on a boiler) connected together, with a single drain line.

Drains are to be separate for each SSV from drip elbow to open floor drain/funnel. SSV discharge piping must be properly sized to prevent blow-back into the plant when valves open.

R70: Section A/M302 will be modified to show individual drains per safety relief valve on a future amendment. This is indicated correctly on the Boiler Flow Diagram detail 1/M503.

Q71: Keyed Note mentions sensors in the Boiler Plant for CO, Combustible Gases (Methane and Propane) and NOx. NOx monitoring in the Boiler Plant is not required by Specification section 23 09 11, and is not typically done in VA Facilities. Provide locations for Methane sensors at (near) Ceiling Height, two places. Provide sensors for Propane at (near) floor level, two locations in main plant.

Consider placing one Propane sensor either in basement, or near floor level adjacent to Basement access.

Provie adequate number of Carbon Monoxide sensors to achieve adequate protection for personnel at all locations in the plant- not only main operating floor but also catwalk/mezzanine levels: any location plant operators may have occasion to be in the plant. Note that "detection radius" for sensors is typically "straight line, unimpeded".

R71: The following modifications shall be made:

1.) Modify Keyed Note 19 on sheet MP101 to remove Nox requirement for gas detection sensor.

2.) Copy modified keyed note 19 from MP101 and ADD as new Keyed Note 27 on MP102; ADD (1) combined sensor at boiler 1 and boiler 3 locations on mezzanine level, ADD (1) combined sensor at south railing between condensate and dearator tanks.

3.) Copy modified keyed note 19 from MP101 and ADD as new Keyed Note 14 on MP103; ADD (1) combined sensor to north railing on upper mezzanine near access ladder.

Q72: Current plant operation has SSV lift setpoints at 150 and 155 psig. Schedule indicates lift pressures of 125 and 130 psig. Recycle Steam Pressure Switches on the boilers are currently set at 125 psig.

R72: Revise "Boiler Schedule" on Sheet M601 as follows: Relief Valve 1 pressure to be 150 psi, Relief Valve 2 pressure to 155 psi.

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……..End of Amendment A0003……..