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NATIONAL BOARD INSPECTION CODE
COMMITTEE
MINUTES
Meeting of January 16, 2014 San Antonio, TX
These minutes are subject to approval and are for Committee use only. They are not to be duplicated or quoted for other than Committee use.
The National Board of Boiler & Pressure Vessel Inspectors 1055 Crupper Avenue
Columbus, Ohio 43229-1183 Phone: (614)888-8320 FAX: (614)847-1828
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1. Call to Order - 8:00 a.m. NBIC Chairman, Don Cook called the meeting to order at 8:05 a.m. 2. Introduction of Members/Visitors The Committee Members and visitors introduced themselves. 3. Announcements Mr. Cook thanked the National Board for the reception the previous night at the Alamo. Mr. Chuck
Withers then presented Mr. Stan Staniszewski with a pin that commemorated his 10 years of service with the NBIC Main Committee. He also thanked all of the members and volunteers for their continued support.
4. Adoption of the Agenda Mr. George Galanes added two new interpretations to the agenda, IN14-0401 and IN14-0501. He
also stated that the action item NB14-0101 was missing from the agenda. This item was assigned to the SG Locomotive Boilers and was approved there. The item will be letter balloted to the SC on Repairs and Alterations.
Mr. Frank Hart stated that a new action item, NB14-1601 was added to the SC on PRD. Mr. Mike Richards stated that there were two action items missing from the agenda, NB13-0102 and
NB12-1401 and two new action items, NB14-1401 and NB14-1501 were added. He also stated that Mr. Brian George was no longer a candidate for membership to the SC Installation. Mr. Todd Creacy was sent by Zurich instead but he will remain as only a member of the SG Boiler and Pressure Vessels and Piping for the time being.
There was a motion to adopt the agenda as modified. The motion was unanimously approved. 5. Approval of the Minutes There was a motion to approve the minutes of the July 2013 meeting. The motion was unanimously
approved. 6. Review of Rosters/Resignations/Nominations/Reappointments (Attachment 1) a. Changes to rosters b. Resignations Mr. Gary Scribner has resigned from all of his committee memberships due to his new position at
the National Board. Mr. John Richardson has resigned from all committee work as his new employer will not support
his participation. Mr. Ray Snyder has retired from his company and has submitted his resignation from all
committee work.
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c. Nominations and reappointments for NBIC Committee members, Subcommittee members and subgroups that serve all four subcommittees.
1. There was a motion to recommend Mr. Bryan Schulte for reappointment to the NBIC
Committee. The motion was unanimously approved pending the approval of the Chairman of the Board of Trustees.
2. There was a motion to recommend Mr. Benjamin Anthony for reappointment to the SC on
PRD. The motion was unanimously approved pending the approval of the Chairman of the Board of Trustees.
3. There was a motion to recommend Mr. Don Patten and Mr. Stan Konopacki for
reappointment to the SC on Installation. The motion was unanimously approved pending the approval of the Chairman of the Board of Trustees.
4. There was a motion to recommend Mr. Ralph Pate for reappointment to the SC on Inspection.
The motion was unanimously approved pending the approval of the Chairman of the Board of Trustees.
5. There was a motion to recommend that Mr. Tom Vandini become a member of the SC on
Inspection representing manufacturers. The motion was unanimously approved pending the approval of the Chairman of the Board of Trustees.
6. There was a motion to recommend Mr. Ed Wiggins as a member of the SC on Installation.
The motion was unanimously approved pending the approval of the Chairman of the Board of Trustees.
7. There was a motion to recommend Mr. David McHugh as a member of the SC on PRD. The
motion was unanimously approved pending the approval of the Chairman of the Board of Trustees.
8. There was a motion to recommend Mr. Kim Beise as a member of the SC on PRD. The
motion was unanimously approved pending the approval of the Chairman of the Board of Trustees.
9. There was a motion to recommend Mr. Brian Morelock as a member of the SC on Repairs
and Alterations. The motion was unanimously approved pending the approval of the Chairman of the Board of Trustees.
d. Elections to NBIC Committee for the three available positions A write in election was held to fill three empty spots on the NBIC Main Committee. The three
individuals that will be recommended for appointment to the Main Committee pending the approval of the Chairman of the Board are;
1. Brian Morelock: representing Manufacturers; 2. Venus Williams representing AIAs; and 3. Kevin Simmons representing valve manufacturers.
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7. Report of Subcommittees
a. Subcommittee on PRD (Attachment 2) Charge: To develop new rules, revise, interpret and maintain existing rules which address administrative and technical requirements for installation, inspection and repairs of pressure relief devices. Membership: Frank Hart (Chair), Kim Beise, Marianne Brodeur, Sid Cammeresi, Alton Cox, Denis DeMichael, Robert Dobbins, Robert Donalson, Thakor Patel, Raymond McCaffrey, David McHugh, Brandon Nutter, Kevin Simmons and Tom Beirne (Secretary). Mr. Hart reported on the following: 2) Inquiries There were no inquiries assigned to the subcommittee.
3) Action Items NB11-0401 - Part 4, SC PRD - The development of a possible fourth part of the NBIC to cover pressure relief topics. (No attachment) January 2014 Mr. Hart gave a progress report. He stated that work was being done to complete a draft of Part 4 to be letter balloted to the NBIC Committee for comment only. He specifically asked that voters not post non-constructive votes or piggy backed votes. The draft will be letter balloted before the next meeting. NB12-0901 – Part 3, SC on PRD - Prepare a guide for repair of tank vents. (No attachment) January 2014 Mr. Hart is gave a progress report. He stated that each manufacturer has its’ own repair guide and it is challenging to find appropriate wording that will apply to all vent types. The subgroup will continue to work on this. NB13-1901 – SC on PRD - Add a provision to the NBIC to allow for the partial disassembly and cleaning of an ASME Section XII valve without changing the set pressure adjustments and without having to do a complete VR. (No attachment) January 2014 Mr. Hart gave a progress report. He stated that Section 12 has included language for cleaning relief valves and the subcommittee is studying this issue more before it makes a recommendation on wording. NB14-0602 – Glossary SC on PRD - Update glossary of all three parts. (No attachment) January 2014 Mr. Hart gave a progress report. He stated that the task group is continuing to work on this item in conjunction with Part 4 development.
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NB14-1601 – Part 3, 1.7.5 SC on PRD – Correct paragraph references. (Attachment 2, pp.10-13) January 2014 Mr. Alton Cox sent an email request to correct paragraph references in this section. There was a motion to approve the corrections. The motion was unanimously approved. b. Subcommittee on Installation (Attachment 3) Charge: Responsible for developing new rules, revising, interpreting and maintaining existing rules which address administrative and technical requirements for installing pressure retaining items. This subcommittee also directs, supports, reviews and approves any items forwarded by each subgroup functioning under this subcommittee. Membership: Michael Richards (Chair), Paul Bourgeois, Geoff Halley, Stan Konopacki, Brian Moore, Don Patten, Paul Schuelke, Melissa Wadkinson, Edward Wiggins, and Jeanne Bock
(Secretary). Mr. Richards reported on the following: 1) Inquiries There were no inquiries assigned to this subcommittee.
2) Action Items
NB08-2101 – Part1, SG on Boilers - CSD-1 does not address solid fuel firing and it would be appropriate for the NBIC to look into it. A task group of G. Halley (PM), M. Richards, G. Scribner and B. Moore has been assigned. (Attachment 3, pp. 14-18) January 2014 Mr. Halley reported with proposed wording. There was as motion to letter ballot this item to the NBIC Committee. The motion was unanimously approved. NB10-0201 - Part 1 S3 - Expand the section on installation of thermal fluid heaters. This action item is a result of splitting NB09-0601into two parts. A task group of D. Patten (PM), M. Wadkinson, G.
Halley, and P. Bourgeois has been assigned. (No attachment)
January 2014 Ms. Wadkinson gave a progress report. She stated that she plans to address all of the comments that she received from the comment only letter ballot and formulate some revised wording to present at the next meeting.
NB10-1201 - Part 1 SC Installation - Request for a format change to NBIC Part 1 Code Rules. A task group of M. Wadkinson (PM), E. Wiggins, S. Konopacki, B. Moore and D. Patten has been assigned. (No attachment) January 2014 Ms. Wadkinson gave a progress report. She stated that the task group on this item has changed and that she would now be the project manager and the Ed Wiggins would join the group as well.
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NB11-1901 - Part 1, SG Fiber Reinforced Plastic - Installation of High Pressure Composite Pressure Vessels. The FRP Subgroup initiated this proposal to provide guidance for a safe installation of high pressure vessels operating in close proximity to the public. (No attachment) January 2014 Mr. Richards gave a progress report. He spoke with Mr. Francis Brown you told him that the task group is still working on this item and hoped to have some new wording by the July meeting. NB12-0302 - Part 1, SG Pressure Vessels and Piping - Define installation requirements for PVHO (hyperbaric chambers). A TG of B. Moore (PM), M. Richards and T. Creacy was assigned. (No attachment)
January 2014 Mr. Richards gave a report of no progress at this time. NB12-1401 - Part 1, SG on Boilers - Reference item NB09-0204. Address the installation of Potable Water Heaters. A task group of P. Bourgeois (PM) and B. Moore was assigned. (Attachment 3, p. 19) January 2014 Mr. Bourgeois reported with proposed wording. Much discussion ensued and it was decided to vote on the item as presented and then open a new action item to massage the wording. There was a motion to approve the proposed wording. The motion was approved with one abstention from Dr. Canonico. NB13-0102 Part 1, S3.6 SG PVP This action item is a result of public review comment PR13-0602. Address through wall CO2
piping. (Attachment 3, p. 20-21) January 2014 Mr. Bourgeois reported on this item with proposed wording. There was a motion to approve the wording. The wording was unanimously approved with a slight wording change. NB13-1101 - Part 1, SG Boilers - Addition of installation requirements for condensing hot water boilers. A TG of G. Halley (PM) M. Wadkinson, D. Patten, B. Moore and P. Bourgeois was assigned. (No attachment) January 2014 Mr. Richards gave a progress report that the item was still being worked on. NB14-0401- Part 1 2.5.3, SG Boilers - Part 1 Installation does not require lockable disconnects. Wording needs to be added to become more uniform with other codes and standards. (Attachment 3, pp. 22-23) January 2014 Mr. Bourgeois reported with proposed wording. There was a motion to approve the proposed wording. The motion was unanimously approved. NB14-0402 – Part 1, SG PVP – Make a word change of Boiler Room to Equipment Room throughout Part 1. (Attachment 3, pp. 24-36) January 2014 Ms. Wadkinson reported with a motion to change the words Boiler room to Equipment room in Part 1
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Installation. The motion was unanimously approved. NB14–0403 – Part 1, SG Boilers – Index proofing. A TG of B. Moore (PM), has been assigned. (No attachment) January 2014 Mr. Richards gave a progress report. He stated that this action item is ongoing. NB14-1401 – Part 1, S3, SG PVP - Edit existing language to be consistent with fire codes. A TG of P. Bourgeois (PM), E. Wiggins, M. Washington, and D. Patten has been assigned. (No attachment) January 2014 Mr. Richards gave a progress report that a task group had been assigned and will continue to work on this for the next meeting. NB14-1501 - Part 1, 2.7.3, SC Installation – Rearrange wording in this section to be grammatically correct and consistent with ASME. (Attachment 3, pp. 37-39) January 2014 Mr. Moore reported with proposed wording. There was a motion to approve the proposal. The motion was unanimously approved. c. SC on Inspection (Attachment 4) Charge: Responsible for developing new rules, revising, interpreting and maintaining existing rules
which address administrative and technical requirements for inspection of pressure retaining items. This subcommittee also directs, supports, reviews and approves any items forwarded by each subgroup functioning under this subcommittee.
Membership: Mark Mooney (Chair), Tim Barker, Domenic Canonico, Mark Horbaczewski, Jim Getter, Greg McRae, Venus Newton, Ralph Pate, Bob Reetz , John Richardson, Jim Riley, Jason
Safarz, Mike Schwartzwalder, Stan Staniszewski, and Bill Smith (Secretary). Mr. Mooney reported on the following: 1) Inquiries
There were no inquiries assigned to this subcommittee.
2) Action Items NB07-0910 - Part 2 S6 SG Inspection Specific - Review DOT supplement. A task group of S. Staniszewski (PM), G. McRae and J. Riley has been assigned. This specific Supplement should be
reviewed by the task group for completeness and accuracy. (No attachment)
January 2014 Mr. Staniszewski gave a progress report. He stated that this could appear in the Federal Registry for the 2015 Edition.
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NB10-0601 - Part 2, SC S6, SG on Fiber Reinforced Plastic- Inspection of high pressure composite
vessels. (No attachment) January 2014
Mr. Mooney gave a progress report. He stated that the SG on FRP is done with the proposal but that the SC needs more time to review it. NB11-0204 - Parts 2 & 3, S2 SG Historical Boilers - Review NDE requirements of stayed areas. A TG of M. Wahl (PM), J. Larson and F. Johnson has been assigned. (No attachment)
January 2014 Mr. Reetz gave a progress report.
NB11-1101 - Part 2, S2.6.2 b), SG on Historical Boilers - This section should be revised to provide more guidelines for evaluating local pitting corrosion versus general corrosion. A TG of D. Rupert (PM), M. Wahl, and R. Bryce has been assigned. (Attachment 4, pp. 40-42)
January 2014 Mr. Reetz reported on this item with proposed wording. There was a motion to letter ballot this item to the NBIC Committee. The motion was unanimously approved. NB12-1501 - Part 2, SG Inspection General - Review inspection requirements so as to align with installation requirements in Part 1. A Task Group of V. Newton, M. Horbaczewski, J. Daiber and J. Safarz was assigned.. (No attachment) January 2014 Mr. Newton gave a progress report. He stated that the task group was taking this item in sections. They are currently working on CO2 and will update the committee as they progress.
NB12-1801 - Part 2, 5.5.2-5.5.3, SG Inspection Specific - Replacement of stamping during inservice inspection. A Task Group consisting of M. Mooney (PM), R. Dobbins, T. Barker, D. Canonico, and Daren Daily was assigned. (Attachment 4, pp. 43-51) January 2014 Mr. Mooney reported that this item had been presented to the subcommittee and the new language was approved but with two disapproved votes and one abstention. He stated that they would like to letter ballot this to the NBIC Committee for comment only and the SC will address the negative comments. There was a motion to letter ballot this item to the Committee. The motion was unanimously approved. NB13-0701 - Part 2, 4.4.7 j) 1) SG Inspection General - Revise wording to clarify the rule in this section. A Task Group consisting of J. Riley (PM), M. Schwartzwalder, and M. Clark was assigned (No attachment) January 2014 Mr. Mooney gave a progress report. He stated that this item will go out to letter ballot for the SG on Inspection Specific.
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NB13-0801 - Part 2, SG on Insp. Spec. – Review inspection requirements for CO2 Tanks. A task group of V. Newton (PM), and R. Pate was assigned (Attachment 4, pp. 52-56) January 2014 Mr. Newton reported with proposed wording. After much discussion it was moved to letter ballot the Main Committee on this item. The motion was unanimously approved.
NB13-0901 – Part 2, S2 SG on Historical Boilers - Review requirements for safety valve discharge piping. A Task Group consisting of F. Johnson and T. Dillon was assigned. (Attachment 4, p. 52)
January 2014 Mr. Reetz reported with proposed wording. There was a motion to letter ballot this item to the NBIC Committee. The motion was unanimously approved. NB13-0902 - Part 2, S2, SG on Historical Boilers - Review alternate methods of Tube Sheet repair. A Task Group consisting of F. Johnson, T. Dillon and M. Wahl was assigned. (No attachment) January 2014 Mr. Reetz gave a progress report. He said that the task group is still coming up with diagrams and illustrations to support this item. He also stated that this item may be switched to Part 3. NB13-0903 – Part 2, S2.14 SG on Historical Boilers – Add language to address the safety concerns when using liquid or gaseous fuels to fire a historical boiler. A Task Group consisting of R. Reetz (PM), T. Dillon, R. Bryce, and J. Larson was assigned. (No attachment) January 2014 Mr. Reetz gave a progress report. He stated that the SG is continuing to work on this. NB13-1002 - Part 2, SG on Insp. Spec. – Review inspection requirements for B31.1 Power Piping. A Task Group consisting of M. Schwartzwalder (PM), J. Frey, V. Newton, M. Mooney, D. Canonico, M. Horbaczewski and B. Dobbins has been assigned. (No attachment) January 2014 Mr. Mooney gave a progress report. He stated that the subgroup was still working on this item. Mr. Schwartzwalder stated that the task group was working on putting together guidelines for inspection of high pressure piping.
NB13-1201 – Part 2, 2.2.10.6, SG Inspection General - This action item is a result of PRC PR13-0209 from Francis Brown. His comment stated, " The NBIC is supposed to be a safety Code so why is a "good practice" only a "good practice" if required by a Jurisdiction. For example 2.2.10. 6 a) is or is not that paragraph a "good practice" mandatory, but without the Jurisdictional requirement a good practice is optional with the owner/user. This section should be revised to indicate "good practices" should be complied with but are mandatory when required by the Jurisdiction. A task group of M. Mooney (PM), V. Newton and J. Safarz has been assigned. (No attachment)
January 2014 Mr. Mooney gave a progress report. He stated that the task group is still working on this.
NB13-1301 - Part 2, SG Inspection General - Review methods of Finite Element Analysis as they pertain to inspection. A Task Group consisting of J. Riley (PM), S. Staniszewski, M. Schwartzwalder, M. Mooney and R. Pate was assigned. (No attachment)
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January 2014 Mr. Mooney gave a progress report. He stated that the task group is getting input from inspectors and that this was a work in progress. NB13-1302 - Part 2, SG Inspection General - Review Cryogenic vessel inspection requirements. A Task Group consisting of J. Riley (PM), A. Renaldo, R. Dobbins, R. Bartley and R. Pate was assigned. (No attachment) January 2014 Mr. Mooney gave a progress report. He stated that the task group is still working on this. NB13-1303 - Part 2, SG Inspection General - Review Inspection requirements for Biomass Fueled Boilers. A Task Group consisting of M. Mooney (PM), M. Horbaczewski, D. Canonico, and J. Safarz was assigned. (No attachment) January 2014 Mr. Mooney gave a progress report. He stated that the task group is working with a document that came from Geoff Halley NB13-1404B - Part 2, SG on LB – Fillet welded staybolts. (No attachment) January 2014 Mr. Reetz gave a progress report. He stated that the SG would look at this item at the March meeting.
NB13-1409 – Part 2, SG on LB – Method for analyzing bulges created by overheating in stayed boiler surfaces. (No attachment)
January 2014 Mr. Reetz gave a progress report. He stated that the SG would look at this item at the March meeting.
NB13-1701 - Part 2, 2.3.6.6 SG Insp. Spec. – Inspection requirements of wire wound pressure vessels. A task group of R. Dobbins (PM), M. Mooney, J. Riley, V. Scarcella and G. Galanes has been assigned. (No attachment) January 2014 Mr. Mooney gave a progress report. He stated that the SG will be letter balloted for comment only. NB14-0501 Part 2 Update index to Part 2. A Task Group consisting of D. Canonico and M. Mooney was assigned. (No attachment) January 2014 Mr. Mooney gave a progress report. He said that this item is ongoing. NB14-0901 – Part 2, SG Inspection Specific – Inspection of High Pressure Vessels (No attachment) January 2014 Mr. Mooney stated that the Subcommittee on Inspection had voted to close this item with no action taken. After some discussion it was decided that more information was needed to move forward with this item. Mr. Mooney stated that he would contact Mr. Brown for further details. NB14-1001 –Part 2, 5.2.1 SG Insp. Spec. - The NBIC does not address replacement of duplicate
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nameplates where the original nameplate is intact and attached to an inner vessel and may or may not be visible. (No attachment) January 2014 Mr. Mooney reported with proposed wording. After much discussion it was decided that the Subcommittee needs to continue to work on this item. NB14-1201 - Part 2, S2.10.3 SG on HB - Delete paragraph S2.10.3 and replace with suggested wording. (No attachment) January 2014 Mr. Reetz reported that the SG on Historical Boilers had looked at the item and had decided to close it with no action taken. They had looked at the mathematical equations proposed and decided that the language had been there for over 10 years and that it had never caused an issue so they decided not to change it. There was a motion to close this item. The motion was unanimously approved. Mr. Reetz will draft a letter to be sent to the commenter to inform him of the committee’s decision and the reasoning behind it. d. SC on Repairs and Alterations (Attachment 5) Charge: Responsible for developing new rules, revising, interpreting and maintaining existing rules which address administrative and technical requirements for repairing or altering pressure retaining items. This subcommittee also directs, supports, reviews, and approves any items forwarded by each subgroup functioning under this subcommittee. Membership: George Galanes (Chair), Brian Boseo, Chad Bryan, Paul Edwards, Craig Hopkins, Wayne Jones, Jim Larson, Lawrence McManoman, Brian Morelock, Ed Ortman, Jim Pillow, Bryan Schulte, Jim Sekely, Mike Webb and Bill Vallance (Secretary). Mr. Galanes reported on the following: 1) Inquiries IN13-0301 - SC on Repair and Alteration, Part 3, 3.2.2 c) - Question 1: Does Part 3, 3.2.2 c) prevent an "R" Certificate Holder with the capabilities within his shop from rolling and welding a shell or other such items as headers, nozzles,(flange to pipe) for replacement in a vessel or boiler has is repairing or altering? Answer 1: No
Question 2: If the answer is No to the above question, if the same Certificate Holder could not fabricate the replacement items within his capabilities and received these parts from an outside source then these items would have to be fabricated by an organization holding the appropriate Code Certificate of Authorization. Answer 2: Yes. (No attachment) January 2014 Mr. Edwards reported that the Subcommittee had voted to refer the inquirer to the previously passed inquiry IN98-28 and let him know that action item NB14-0701 has been opened to clarify the language in this section. There was a motion to approve this response to the inquirer. The motion was unanimously approved.
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IN14-0101 – Part 3, 5.7.5, SC on Repairs and Alterations - Question: Is it acceptable ti “NA” on Name plates shown in Figures 5.7.5b) and 5.7.5 c)for the fields “AT____,____˚F” for alterations or re-ratings performed on a Power Boiler constructed in accordance with ASME Section I? Reply: Yes (Attachment 5, p. 58) January 2014 Mr. Ron Pulliam reported with a proposed response to the inquirer. There was a motion to approve this response. The motion was unanimously approved. IN14-0201 – Part 3, 1.8.5 q), SC on Repairs and Alterations - Question: If audit personnel are qualified in accordance with the requirements of ANS/ASME N45.2.23, Qualification of Quality Assurance Program Audit Personnel for Nuclear Power Plants may they perform the audits specified in 1.8.5 q)? Reply: Yes. NQA-1 is based upon ANSI/ASME N45.2-1977and the seven daughter standards of N45.2 including ANSI N45.2.23, Qualification of Quality Assurance Program Audit Personnel for Nuclear Power Plants. The qualification requirements are equivalent. January 2014 Mr. Edwards reported with a proposed response to the inquirer. There was a motion to approve this response. The motion was unanimously approved. (Attachment 5, p. 59) IN14-0301 – Part 3, 3.3.2 d) 1), SC on Repairs and Alterations - Question: Is a standard threaded fitting (such as depicted in ASME Section VIII Figure UW-16.2 sketch L) which is welded through a vessel shell considered to be a nozzle as stated in Section 3.3.2 d) 1)? Reply: No (No attachment) January 2014 Mr. Pillow reported that a task group of Mr. Marty Toth (PM) and Mr. Brian Morelock has been assigned to address this inquiry. IN14-0401 - Part 3, 1.2 - Question 1: The NBIC Part 3 paragraph 1.2 states that a repair shall be carried out “insofar as possible to the section and edition of the ASME code most applicable to the work planned.” If a vessel is constructed using SA-517-E (P-11B) material to ASME Section VIII Div. 1, where production and weld procedure impact tests were required during construction, would a repair to a crack in the shell require production and weld procedure impact testing under the NBIC? Proposed Reply 1: Yes. (No attachment) Question 2: If the answer to Question 1 is yes and there was no SA-517-E material from the original lot available, would the repair require the addition of new base material (e.g. a flush patch around the area of the crack) so that production impact tests could be performed with the original base metal to the new base metal? Proposed Reply 1: Yes. Question 3: If the vessel described in Question 1 was to be altered by adding an SA-675 (P-1) pump flange to the shell, would production and weld procedure impact tests be required using the same lot P-1 and P-11B base materials as used in the alteration? Proposed Reply 1: Yes. January 2014 A task group of Walt Sperko, Bob Wielgoszinski (PM), and George Galanes will work on this inquiry.
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IN14-0501 - Part 3, Section 3.3.4.3 d) Inquiry: Does the NBIC Part 3 in Section 3.3.4.3 d) require tubes below “t min” to be repaired? Reply: No. The NBIC Part 3 does not provide rules for determining when a repair must be performed. (Attachment 5, p. 60)) January 2014 There was a motion to letter ballot this inquiry to the NBIC Committee. The motion was unanimously approved. 3) Action Items NB10-0110 - Part 3 S6.19.1 TG on DOT - Combine and clarify requirements within S6.15 for TR- Forms, S6.18 Preparation of TR-Forms and S6.19 for Reports of Repairs, Alterations and Modifications. (No attachment) January 2014 Mr. Galanes reported that this item should be closed as it has already been approved via letter ballot. A new item, NB14-2001 was opened to address the comments received by Mr. Webb as a result of this item.
NB11-1001 - Part 3, 3.3.4.9, SG on R/A Specific - Tube plugging for fire tube boilers. ATG of A. Bramucci (PM), W. Jones, and R. Miletti has been assigned. (No attachment)
January 2014 Mr. Bramucci gave a progress report. The task group will continue to work on this item for the July meeting. NB11-1201 - Part 3, 1.8, SG on R/A General- Revise Part 3, 1.8 “NR” Accreditation requirements to include repairs to ASME Section III stamped components. A TG of P. Edwards (PM), P. Fisher, K. Kavanaugh, R. McIntyre, C. Smith, C. Withers, B. Schaefer, and B. Wielgoszinski has been assigned (No attachment) January 2014 Mr. Edwards reported that the TG plans to Letter Ballot the Subcommittee on Repair and Alteration and the Main Committee before the next meeting. NB12-0403 - Part 3, SG R/A Specific - CSEF Weld Repair Options. A TG ofGeorge Galanes and EPRI representatives has been assigned. (No attachment) January 2014 Mr. Galanes reported that they plan to letter ballot the Subcommittee on Repair and Alteration and
then move it up to the Main Committee before the next meeting.
NB12-0801 - Part 3, SG R/A Specific-Repair and Alteration of Gasketed PHE’s in the field. A TG of E. Ortman (PM), J. Pillow, G. Galanes, B. Wielgoszinski has been assigned. (No attachment)
January 2014 Mr. Ortman gave a progress report. He stated that he would like to letter ballot the SG on Repair and Alteration Specific and the Subcommittee on Repair and Alteration before the next meeting.
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NB13-0502- Part 3, 2.5.3 e), SG R/A Specific - Clarify the wording in this section to state, “After the finished weld has reached ambient temperature and when required by the specific welding method, the surface temper bead reinforcement layer has been removed substantially flush with the surface of the base metal, the weld shall be examined again by either of the above methods to determine that no defects exist using acceptance standards acceptable to the Inspector or original code of construction. (Attachment 5, pp. 61-66)
January 2014 Mr. Pillow reported with proposed wording. There was a motion to approve the wording. The
motion was approved with one abstention from Dr. Canonico. NB13-0503 - Part 3, 5.7.2 c) and 5.7.3 SG R/A General - Add wording in these sections to address
attaching nameplates. (Attachment 5, p. 67) January 2014 Mr. Pulliam reported with proposed wording. There was a motion to approve the proposed wording.
The motion was unanimously approved. NB13-1401 - Part 3, S.9.2, SG LB - Add wording in this section regarding boiler tube welding. (No
attachment) January 2014 Mr. Reetz gave a progress report. He stated that the Subgroup on Locomotives is meeting in March
and he should have more information at the July meeting. NB13-1403 - Part 3, S1.9.2 SG LB - Installation of Boiler and Arch Tubes. (No attachment) January 2014 Mr. Reetz gave a progress report. He stated that the Subgroup on Locomotives is meeting in March
and he should have more information at the July meeting. NB13-1404-A - Part 3 S1, SG LB - Fillet welded staybolts. (No attachment) January 2014 Mr. Reetz gave a progress report. He stated that the Subgroup on Locomotives is meeting in March
and he should have more information at the July meeting. NB13-1405 - Part 3, S1.2.9 SG LB - Throttle pipes, dry pipes, superheater headers and front end
steam pipes. (No attachment) January 2014 Mr. Reetz gave a progress report. He stated that the Subgroup on Locomotives is meeting in March
and he should have more information at the July meeting. NB13-1406 - Part 3, S1, SG LB - Superheater units. (No attachment) January 2014 Mr. Reetz gave a progress report. He stated that the Subgroup on Locomotives is meeting in March
and he should have more information at the July meeting.
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NB13-1407 - Part 3, S1 SG LB Bolts, nuts and studs. (No attachment) January 2014 Mr. Reetz gave a progress report. He stated that the Subgroup on Locomotives is meeting in March
and he should have more information at the July meeting. NB13-1408 - Part 3, S1 SG LB- Threaded boiler studs-Taper thread and straight thread types. (No attachment) January 2014 Mr. Reetz gave a progress report. He stated that the Subgroup on Locomotives is meeting in March
and he should have more information at the July meeting. NB14-0201 – Part 3, SG R/A Specific - Tube Plugging with weld metal. (No attachment) January 2014 Mr. Pillow reported that the Subcommittee had considered this information and decided to close this item with no action taken. There was a motion to close this item. The motion was unanimously approved. NB14-0202 Part 3 RA Index – Review and update of Part 3 RA Index. A task group of B. Schaefer
(PM), and J. Pillow has been assigned (No attachment) January 2014 Mr. Schaefer reported that as the task group makes progress a letter ballot will be issued.
NB14-0301 Part 3, 3.3.3 and 3.4.2 SG R/ A Specific- This item is a result of IN13-0501. Write rules for encapsulation. A TG of Brian Boseo (PM), Bob Wielgoszinski, Bryan Schulte and George Galanes was assigned. (No attachment)
January 2014
A progress report was given. The task group is looking at developer’s wording for encapsulation. There is a plan to letter ballot the SG for comment only.
NB14-0302 - Part 3, S6.15 SG on R/A Spec. – Development of TR Forms.
January 2014 Mr. Staniszewski reported that he will report as soon as the DOT gives him their report.
NB14-0701 Part 3, 3.2.2 c) SG on R/A Gen. This action item is a result of IN13-0301. The rationalization is to support an intent interpretation that addresses an R-Certificate holder's capability to fabricate ASME pressure parts to be used in repair or alteration being performed by the same R-Certificate holder who is fabricating the ASME pressure part. The current words in NBIC Part 3 do not support this. (No attachment)
January 2014 Mr. Wielgoszinski gave a progress report. He stated that this item is to propose new wording for making replacement parts in the shop and installing them in the field without it being stamped as an ASME code stamped part.
Page 16 of 17
NB14-1301 Part 3, 5.2.2 b), 5.7.5 a) SG R/A Spec. Revise the data field for temperature on the alteration and re-rating nameplates. January 2014 Mr. Galanes reported that this item was already discussed with interpretation IN13-0401. NB14-0101 - Part 3, S2 SG HB Complete Barrel Replacement An entire course of a barrel may be replaced as a repair provided that: a) Tensile strength of a new material meets or exceeds the original material. (No attachment) January 2014 Mr. Reetz gave a progress report. NB14-0204 - Part 3, 1.8, SG R/A General - Review this section for NR Accreditation requirements. The administrative requirements have been removed and we should have a TG review if we want to remove any of the existing requirements in the NBIC Part 3 before we publish the 2015 Edition. (No attachment) January 2014 A TG of Randy Cauthon (PM), Rob Trout and Nathan Carter has been assigned.
8. Liaison Activities
a. ASME - Paul Edwards Mr. Edwards gave a brief synopsis of current ASME events and also provided a handout. (Attachment 6, p. 68)
b. I.C.C.- Chuck Withers
Mr. Gary Scribner spoke in Mr. Wither’s absence. He stated that we are providing guidance for developing a solar code and have submitted comments regarding the Green code and how the NBIC and the ASME Codes conflict with it.
c. AWS - Mr. Jim Sekely was not present at this meeting to make a report.
d. API - Mr. Jim Riley was not present at this meeting to make a report.
e. P.C.C. – There was not a representative present at the meeting to make a report. 9. New Business NB13-0401 – NB-240, NBIC Committee- Address proposed changes to the NBIC as a result of the 2013 audit. (Attachment 6, pp. 69-92) January 2014 Mr. Cook reported on some proposed changes to NB-240. There was a motion to letter ballot these changes. The motion was unanimously approved.
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23
NATIONAL BOARD INSPECTION CODE
SECTION 1
2013
SEC
TIO
N 1
PART 3 — REPAIRS AND ALTERATIONS
i) Repair and Inspection Program
The repair and inspection program section shall include reference to a document (such as a report, traveler,
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valves. ����������������������������������������������������������������������������������������
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1) Each valve or group of valves shall be accompanied by the document referred to above for process-
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number, etc.) appearing on the repair documentation and repair nameplate such that traceability is
established.
2) The document referred to above shall describe the original nameplate information, including the
ASME Code symbol stamping and the repair nameplate information, if applicable. In addition, it shall
include material checks, replacement parts, conversion parts (or both), reference to items such as
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test methods to be used. Application of the “VR” stamp to the repair nameplate shall be recorded in
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on the document. There shall be a space for “signoffs” at each operation to verify that each step has
been properly performed.
3) The system shall include a method of controlling the repair or replacement of critical valve parts. The
method of identifying each spring shall be indicated.
4) The system shall also describe the controls used to ensure that any personnel engaged in the repair
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j) Welding, NDE, and Heat Treatment (when applicable)
The quality system manual shall indicate the title of the person(s) responsible for and describe the system
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& S7.13.
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< � 3������������F�����+������"�������������������������������?@�B�:���������D����������������
required in NBIC Part 3, 1.7.7.5 i). Similarly, NDE and heat treatment techniques must be covered in
the quality system manual. When outside services are used for NDE and heat treatment, the quality
system manual shall describe the system whereby the use of such services meet the requirements
of the applicable section of the ASME Code.
k) Valve Testing, Setting, and Sealing
The system shall include provisions that each valve shall be tested, set, and all external adjustments
sealed according to the requirements of the applicable ASME Code Section and the National Board. The
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A13
A131.7.5.4 i)
Page 10 of 92
274
NATIONAL BOARD INSPECTION CODE
SECTION 11
2013
SEC
TIO
N 1
1
PART 3 — REPAIRS AND ALTERATIONS
Examination —
Part 1 (5.4); Part 2 (2.3.3), (2.3.5.4), (2.3.6),
(2.4.5), (Section 4), (5.3.1), (5.3.8),
(S1.4.2), (S2.4), (S2.4.4), (S2.5);
Part 3 (3.3.4.2), (Section 4), (4.4), (S4.2),
(S4.13.1), (S4.15), (S6.17), (S4.17.6),
(S5.2), (S6.10), (S6.12), (S6.17)
Examples or Repairs and Alterations —
Part 3 (3.3.3), (3.4.3)
Exfoliation —
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Exhibits —
!����;�%��X�[��Y�Z &�%������[Y�Z &�%��\�[��Y�Z
Exit and Egress —
Part 1(2.4.1), (2.5.3), (3.4.1)
Expansion Tanks —
Part 1 (3.7.9.1), (3.7.9.2); Part 2 (2.3.6.3)
Expansion and Support —
Part 1 (2.7.3), (3.3.1), (3.7.9), (3.9.4), (4.3.3);
Part 2 (2.4.7)
External Inspections,
Boilers —
Part 2 (2.2.5)
Pressure Vessels —
Part 2 (2.3.3), (S7.4)
Piping —
Part 2 (2.4.4)
Graphite —
Part 2 (S3.4)
FRP —
Part 2 (S4.4), (S4.7)
External Weld Metal Buildup —
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F
Failure Mechanisms —
Part 2 (3.4), (S6.6.4)
Fatigue —
Part 2 (3.4.1), (5.3.8.6)
Federal Railroad Administration (FRA) —
Part 2 (S1.3); Part 3 (S1.1.1)
Feedwater —
Part 1 (2.5.1), (3.7.4); Part 2 - (2.2.10.4),
(2.2.12.5), (S2.7.1), (S2.14), (S2.7.1)
Fiber-Reinforced Thermoset Plastic
Equipment (RTP, FRP) —
Part 2 (Supplement 4); Part 3 (Supplement 4)
Field Repairs for Relief Devices —
Part 3 (S7.7)
Firebox —
Part 2 (2.2.10.2), (2.2.12.9), (S1.1), (S1.4.2),
(S2.11); Part 3 (S1.2.10.2), (S1.2.11.1),
(S2.13.10.4), (S2.13.11)
Fire Damage —
Part 2 (5.3.8.5), (5.7.7), (S7.4)
Fittings —
Part 1 (3.8); Part 3 (S1.2.13)
Flanges —
Part 1 (5.2.3); Part 2 (2.2.10.3);
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Forced-Flow Steam Generators —
Part 1 (2.9.2)
Forms —
Part 1 (1.4.1); Part 2 (5.5), (S2.12);
Part 3 (Section 5), (S6.15)
Distribution —
Part 3 (5.3), (5.4)
Guide for Completing —
Part 3 (5.2), (5.13)
Registration —
Part 3 (5.5.1), (5.5.2)
Foundations —
Part 1 (2.3.1)
(1.7.5.4 [p])
Page 11 of 92
279
NATIONAL BOARD INSPECTION CODE
SECTION 11
2013
SEC
TIO
N 1
1
PART 3 — REPAIRS AND ALTERATIONS
Owner-User Inspection Organization —
Part 3 (1.6.1), (3.3.5.2), (3.4.4.1)
P
Parts —
Part 1 (2.6.3.3), (2.9.2), (3.7.4), (3.7.7), (8.4),
(S1.3); Part 2 (2.3.5), (2.1), (2.2.6), (2.2.7),
(2.2.10), (2.2.12), (2.3.4), (2.3.5), (2.3.6),
(2.5.7), (2.5.8), (8.4); Part 3 (1.7.7.5),
(1.8.5), (3.2.2), (3.3.3), (4.5.1), (4.5.4),
(5.2.2), (5.9.6.5), (5.12), (8.4), (S2.7.2),
(S2.13), (S3.2), (S3.5), (S4.9), (S5.3.1),
(S5.6), (S7.2)
Patch Bolts —
Part 3 (S1.2.8)
Patches —
Part 3 (3.3.4.6), (S1.2.11.2), (S2.13)
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Part 3 (2.2.3), (S4.10.2), (S6.8.3), (S7.12.3)
Performance Testing —
Part 3 (4.5)
Permissible Mounting (SV) —
Part 1 (2.9.5.1), (3.9.1), (3.9.4), (4.5.6), (5.3.6)
Personnel Safety —
Part 1 (Introduction), (4.5.6), (5.3.6), (S1.5);
Part 2 (Introduction), (1.4), (S2.4.3),
(S6.11); Part 3 (Introduction), (S2.3),
(S2.14)
Piecing Tubes/Pipe —
Part 3 (3.3.4.5), (S2.13.7)
Pilot Operated Safety Relief Valves —
Part 2 (2.5.1); Part 3 (S7.14.3)
Piping —
Part 1 (3.7.6), (3.9.1.5), (4.3.3), (Section 5);
Part 2 (2.4), (2.5.5.2), (S2.8.1), (S2.9);
Part 3 (3.3.4.5), (S1.2.13), (S8.3)
Pitting Corrosion —
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Plug Stitching —
Part 3 (S3.5.3.1)
Pneumatic Testing —
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Portable Tank (DOT) —
Part 2 (S6.14)
Post-Inspection Activities —
Part 2 (1.5.4), (S2.4.2), (S6.12.3)
Postweld Heat Treatment —
Part 3 (2.5.2), (S2.10), (S6.9.2), (S7.13.2)
Potable Water Heaters —
Part 1 (3.2.3), (3.7.5.2), (3.7.7.2)
Preheating —
Part 3 (2.5.1), (S2.10), (S6.9.1), (S7.13.1)
Pre-Inspection Activities —
Part 2 (1.5.2), (2.2.3), (S2.4.1), (S6.12.1)
Preparation of Forms —
Part 1 (1.4.5); Part 2 (5.5); Part 3 (5.2.1),
(5.2.2)
Preservation —
Part 2 (S1.5.4), (S2.13.2), (3.3.3)
Pressure Control —
Part 1 (3.8.1.4)
Pressure Gages —
Part 1 (2.8.2), (4.4.2); Part 2 (2.2.10.5),
(2.3.5.1), (2.4.8.1), (S1.4.2), (S2.8.5);
Part 3 (4.3)
Pressure Relief Devices —
Part 1 (2.9), (3.9), (4.5); Part 2 - (2.2.10.6),
(2.5); Part 3 (4.5), (5.9)
Mounting —
Part 1 (2.9.5.1), (3.9.1.1), (4.5.3), (5.3)
(1.7.5)
Page 12 of 92
280
NATIONAL BOARD INSPECTION CODE
SECTION 11
2013
SEC
TIO
N 1
1
PART 3 — REPAIRS AND ALTERATIONS
Pressure Relief Valve Nameplates —
Part 3 (5.9.2), (5.9.3), (5.9.4), (5.9.5), (5.9.6),
(Supplement 7), (Supplement 8)
Pressure-Reducing Valves —
Part 1 (Supplement 2)
Pressure Testing —
Part 2 (4.3.1)
Alterations —
Part 3 (4.4.2)
FRP Vessels —
Part 3 (S4.15), (S4.17.6)
Inservice —
Part 2 (4.3.1)
Installation —
Part 1 (2.10.2)
Parts —
Part 3 (4.5.4)
Repairs —
Part 3 (4.4.1)
Yankee Dryers —
Part 1 (1.5); Part 2 (2.3), (2.5.5.2), (S5.6)
Pressure Vessels,
Fiber-Reinforced Thermosetting Plastic
(FRP) —
Part 2 and Part 3 (Supplement 4)
Graphite —
Part 2 and Part 3 (Supplement 3)
Inspection —
Part 2 (2.3)
Installation —
Part 1 (Section 4)
LP Gas (Propane) —
Part 2 (Supplement 7)
Relief —
Part 2 (2.3.5.2)
Section VIII Div 2 or 3 —
Part 3 (3.3.5), (3.4.4)
Yankee Dryers —
Part 1 (Supplement 1); Part 2 and Part 3
(Supplement 5)
Process Variables (Corrosion) —
Part 2 (3.3.3.1)
Provisions for Expansion/Support —
Part 2 (2.4.7); Part 3 (S1.2.3), (S1.2.5),
(S1.2.10), (S2.13)
Pumps —
Part 1 (2.5.1.3)
Q
Quality Systems —
Part 3 (1.6.5), (1.7.7), (1.8.5), (S7.10.4)
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FRP Performance —
Part 3 (S4.10.2)
Inspector —
Part 2 (S4.5), (S6.4); Part 3 (S4.2)
NDE —
Part 3 (4.2)
PRV Personnel —
Part 3 (S7.11)
Welders Performance —
Part 3 (S7.12.3), (2.2.3), (S6.8.3)
Quick-Actuating Closures —
Part 2 (2.3.6.5)
Quick-Disconnect Couplings —
Part 2 (2.4.8.3)
R
“R” Symbol Stamp —
Part 3 (1.6)
Radiography —
Part 2 (4.2.5); Part 3 (1.8.5.1)
Records Review —
Part 2 (2.2.11), (2.3.5.4); Part 3 (1.8), (3.2.1),
(3.4.1), (S2.12), (S3.2), (S3.3), (S4.10.3),
(S4.17.5), (S6.4), (S7.4)
(1.7.5)
Page 13 of 92
NB08-2101
1
Part 1, Section 6 Supplement 4
Installation of Biomass (Wood/Solid Fuel) Fired Boilers
(Draft for Review and Comment January 2014)
S4.1 – Scope
NBIC Part 1, Section 6, Supplement 4 provides requirements for the installation of Biomass (Wood/Solid Fuel) Fired Boilers as defined in NBIC Part 1, Glossary.
S4.2 PURPOSE a) The purpose of these rules is to establish minimum requirements, for the installation
of Biomass Boilers. b) It should be recognized that many of the requirements included in these rules must be
considered in the design of the boiler by the manufacturer. However, the owner-user is responsible for ensuring that the installation complies with all the applicable requirements contained herein. Further the installer is responsible for complying with the applicable sections when performing work on the behalf of the owner user.
c) This supplement provides requirements for the installation and control of boilers which use biomass as a major fuel component and will address the differences that occur when solid fuels, such as Biomass, are being used. Thus the primary thrust of this section will be directed toward the control of the fuel handling and distribution systems.
d) Fuels will vary widely depending upon source, moisture content, particle size and distribution, however once the fuel has been established, the owner-user should adhere to the original specification, as closely as possible in order to minimize handling, combustion and emissions problems.
e) Additionally the emissions control equipment is designed around the initial fuel specification. Any changes in fuel fired will impact on the performance of the various elements of the emissions control system.
f) Biomass boilers and boiler rooms require additional considerations than traditionally fueled boilers that may include
Transportation of the fuel from a storage facility to a metering device within the boiler room
Transportation of the metered fuel to the boiler, for distribution to a combustion system whether it be a grate upon which the combustion takes place, a bubbling fluidized bed, circulating fluidized bed or suspension burner.
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NB08-2101
2
In grate based combustion systems combustion air is typically divided into an underfire air system and an overfire air system, each of which must be closely controlled in order to produce clean, efficient combustion.
Induced draft fans to overcome the pressure drop of the emissions control equipment
A fly ash or carbons recycle system, to return unburned carbon to the combustion zone.
An ash removal system, to move ash from the boiler and emissions control equipment to suitable cooling and storage area.
S4.3 – Determination of Allowable Operating Parameters
The allowable operating parameters of the combustion side shall be installed in accordance with jurisdictional and environments requirements, manufacturer’s recommendations, and/or industrial standards, as applicable.
S4.4 – General Requirements
a) Power Boilers utilizing biomass as the primary fuel source shall meet the requirements of NBIC Part 1, Section 2 and this supplement.
b) Steam Heating, Hot Water Heating, and Hot Water Supply Boilers utilizing biomass as the primary fuel source shall meet the requirements of NBIC Part 1, Section 3 and this Supplement.
S4.5 – Fuel System Requirements and Controls
a) Fuel Transport Systems shall address preserving fuel particle size distribution, fire prevention, and the suppression of fires or explosions. In a single installation various types of fuel transportation systems may co-exist, the most common systems are
Conveyor systems- In these systems fuel is dropped onto a moving belt, bucket elevator, drag link conveyor or a screw or auger mechanism. Speed of the conveyor may be varied to meet fuel demand.
Lean phase pneumatic systems - In these systems fuel is dropped into a moving airstream, mixes with the air, and travels through a pipe at a velocity of approximately 5000 ft/min. Air pressures are in the region of 25 inches water column.
Dense phase pneumatic systems – An intermittent or batch feed system, in which fuel is dropped through a valve (dome valve) into a pressure vessel. When the vessel is filled, the valve is closed, air at a pressure between 30
Page 15 of 92
NB08-2101
3
to 100 psig is admitted and the fuel leaves the vessel in the form of a “slug”. The sequence then repeats. (Note that these systems are also used for ash handling.)
a) Fuel Transport Solid Fuel Metering Systems vary depending upon the fuel used and the particle size distribution, these metering systems include but are not limited to:
Variable speed augers Variable speed, helically flighted, augers can be located in the bottom of a fuel metering bin. Alternatively they could be a part of a retort type stoker. The auger dimensions, flighting, and speed range are selected on the basis of fuel being burned, its size range, heating value and required boiler turndown range. The metered fuel typically is then dropped into the throat of a venturi, (or in some cases a plain pipe) though which the fuel transport air flows to carry the fuel into the boiler combustion zone, for distribution on a grate, upon which the burning of the fuel takes place.
Variable speed air-lock valves This valve is basically a rotating slotted cylinder, operating within an outer cylinder, suitably sealed to prevent leakage. Rotational speed and slot dimensions can be varied to accommodate changes in fuel flow rate. The fuel passing through the valve, typically, is deposited onto a moving grate type stoker.
Variable stroke rams This is another device that can be located on the bottom of a metering bin, is typically used on smaller units and is essentially a batch feed mechanism. The stroke of the ram is adjusted to set fuel flow rate.
S4.6 – Combustion Requirements
a) Overfire Air/Underfire Air Distribution When solid fuels are burned on a grate, rather than in fluidized bed units or in suspension, it is normal practice to introduce some of the combustion air under the grate, or bed, and the remainder over the bed. In many cases fuel transport air becomes a part of the over-the-bed combustion air. The proportioning of the overfire to underfire airflow rates is dependent upon several factors, such as fuel particle size, fuel density, burn rate and volatiles. In general the objective is to get as complete a burn on the grate as possible, without creating large quantities of particulate emissions, and then using the overfire air to complete burning of the volatile and small particulate matter, leaving the fuel bed. Loss of combustion air from either the underfire or overfire source shall cause shutoff of the fuel supply and a lockout condition. The control system shall be capable of maintaining the correct relationship between underfire air and overfire air, over the complete firing range of the boiler, while promoting complete burning with minimum particulate emissions.
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NB08-2101
4
b) Programming Controls Programming controls may be relay based, or on more current units, PLC based. Interactive graphics displays may also be incorporated into the system. Access to PLC based controls and interactive graphic displays shall be limited to qualified individuals and password protected. PLC functions shall be confined to the normal boiler operating logic, covering startup, interlocks, and normal shutdown sequences. PLC logic shall not interfere with, or over-ride safety controls, which cause boiler safety shutdown when activated. Consideration should be given to having the PLC logic comply with the requirements of NFPA-85.
c) Pre-firing Checks/interlocks In addition to the Safety Controls defined in Section 4.5 and 4.6 proof of air handling fans or blowers are operating properly shall be required. This includes:
Induced draft fans
Fuel transport fans
Underfire air and Overfire air fans, and
Carbon, or flyash, re-injection fans.
In cases where variable speed drives are used on fans, the combustion system manufacturer’s instructions shall be followed in terms of the allowable upper and lower limits of the power supply frequency (Hz).
d) Pre-purging Pre-purging the boiler and its venting system shall be required. Unless defined otherwise by the manufacturer of the fuel burning equipment, the pre-purge may be achieved by operating the induced draft fan prior to starting the remaining fans in the installation. Purge air volume shall be set during commissioning by the combustion system manufacturer, or the manufacturer’s representative, in accordance with applicable Codes or Standards and shall not be capable of being reset by operating personnel.
e) Ignition Systems Solid fuel ignition systems and/or methods can vary from the placement of manually ignited, oil soaked rags on the fuel bed, to gas or oil fired pilot burners or lances but in all cases shall be in accordance the manufactures recommendations.
f) Firing Rate Control and Fuel/Air Ratio Control The control system shall be capable of maintaining the desired air to fuel ratio over the entire firing range of the boiler, while promoting clean, stable combustion.
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NB08-2101
5
g) Re-injection Systems In installations where fly ash is re-injected from a multi-cyclone collector into the combustion zone for carbon re-burn; precautions should be taken to ensure that plugging of the reinjection pipe work does not occur. Consideration should be given to installing cleanouts in the pipe work.
h) Shutdown and Post Purge Unless the boiler manufacturer’s instructions state otherwise, the fuel supply shall be terminated at shutdown, and the overfire air should remain on until the fuel bed is burned out, and the residue cooled.
New definitions
Conveyor system(s) - A fuel transport system utilized on biomass boilers that drops fuel onto a moving belt, bucket elevator, drag link conveyor or a screw or auger mechanism. (The Speed of the conveyor may be varied to meet fuel demand.) Lean phase pneumatic system(s) - A fuel transport system utilized on biomass boilers that drops fuel into a moving airstream, mixes with the air, and travels through a pipe at a velocity of approximately 5000 ft/min. Air pressures are in the region of 25 inches water column. Dense phase pneumatic system(s) – A batch feed transport system used on solid fuel fired boilers for both fuel delivery and/or ash removal. In this system the material to be transported is dropped through a valve in a pressure vessel. When the vessel is filled the valve closes and air at a pressure from 30 tom 100 psig is admitted and the material leaves the vessel in the form of a “slug”. The sequence then repeats.
Page 18 of 92
NB12-1401 3.5.3 ELECTRICAL a) All wiring for controls, heat generating apparatus, and other appurtenances necessary for the operation of the boiler or boilers shall be installed in accordance with the provisions of national or international standards and comply with the applicable local electrical codes. b) A manually operated remote shutdown switch or circuit breaker shall be located just outside the boiler room door and marked for easy identification. Consideration should also be given to the type and location of the switch to safeguard against tampering. c) If the boiler room door is on the building exterior, the switch shall be located just inside the door. If there is more than one door to the boiler room, there shall be a switch located at each door of egress. 1) For atmospheric-gas burners, and oil burners where a fan is on a common shaft with the oil pump, the complete burner and controls should be shut off. 2) For power burners with detached auxiliaries, only the fuel input supply to the firebox need be shut off. d) Controls and Heat Generating Apparatus 1) Oil- and gas-fired and electrically heated boilers and water heaters shall be equipped with suitable primary (flame safeguard) safety controls, safety limit controls, and burners or electric elements as required by a nationally or internationally recognized standard. 2) The symbol of the certifying organization that has investigated such equipment as having complied with a nationally recognized standard shall be affixed to the equipment and shall be considered as evidence that the unit was manufactured in accordance with that standard. 3) These devices shall be installed in accordance with jurisdictional and environmental requirements, manufacturer’s recommendations, and/or industry standards, as applicable. e) Potable Water Heaters 1) A disconnecting means capable of being locked in the open position shall be installed at an accessible location at the heater so that the heater can be disconnected from all sources of potential. This disconnecting means shall be an integral part of the heater or adjacent to it. 2) a) All wiring for controls, heat generating apparatus, and other appurtenances necessary for the operation of the potable water heaters shall be installed in accordance with the provisions of national or international standards and comply with the applicable local electrical codes. b) A manually operated remote shutdown switch or circuit breaker shall be located just outside the equipment room door and marked for easy identification. Consideration should also be given to the type and location of the switch to safeguard against tampering. c) If the equipment room door is on the building exterior, the switch shall be located just inside the door. If there is more than one door to the equipment room, there shall be a switch located at each door of egress. 1) For atmospheric-gas burners, and oil burners where a fan is on a common shaft with the oil pump, the complete burner and controls should be shut off. 2) For power burners with detached auxiliaries, only the fuel input supply needs be shut off.
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NB13‐0102
S3.6Valves,Piping,Tubing,andFittings
b)SafetyRelief/VentLines–Safetyrelief/ventlinesshallbeasshortandstraightaspossible
withacontinuousroutingtoanunenclosedareaoutsidethebuildingandinstalledinaccordance
withthemanufacturer’sinstructions.Theventline(s)shallbeacontinuousrunfromthevessel
PRDventpipingsafetyreliefvalvetotheoutsideventlinedischargefitting,withoutanysplices.
Mechanicaljointsinmetallicpipingandtubingshallbevisibleandinspectable.Anysplicesin
plasticorpolymerictubingshallbedonewithinthreefeetofthevesselandmustbevisibleand
inspectable.Theselinesshallbefreeofphysicaldefectssuchascrackingorkinkingandall
connectionsshallbesecurelyfastenedtotheLCDSVandthefillbox.Allsafetyrelief/ventlinesshall
beprotectedbymetallicprotectiontopreventpenetrationbynail,projectile,orotherforeignobject
whenroutedthroughawall,floor,orceiling.Theminimumsizeandlengthofthelinesshallbein
accordancewithNBICPart1,TablesS3.6aandS3.6b.Fittingsorotherconnectionsmayresultina
localizedreductionindiameterhavebeenfactoredintothelengthsgivenbytheNBICPart1,Tables
S3.6aandS3.6b.Note:DuetothedesignoftheLCDSVthedischargelinemaybesmallerindiameter
thanthereliefvalveoutletsizebutshallnotbesmallerthanthatshowninNBICPart1,TablesS3.6
a)andb).
Page 20 of 92
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NB14‐0401
Action Item Request Form
8.3 CODE REVISIONS OR ADDITIONS
Request for Code revisions or additions shall provide the following:
a) Proposed Revisions or Additions
For revisions, identify the rules of the Code that require revision and submit a copy of the appropriate
rules as they appear in the Code, marked up with the proposed revision. For additions, provide the
recommended wording referenced to the existing Code rules.
Existing Text:
Part1 Installation does not address lockable disconnects for power, heating and hot water supply boilers.
2.5.3 ELECTRICAL
a) A disconnecting means capable of being locked in the open position shall be installed at an accessible location at the boiler so that the boiler can be disconnected from all sources of potential. This disconnecting means shall be an integral part of the boiler or adjacent to it.
3.5.3 ELECTRICAL
a) All wiring for controls, heat generating apparatus, and other appurtenances necessary for the operation of the boiler or boilers shall be installed in accordance with the provisions of national or international standards and comply with the applicable local electrical codes.
b) A manually operated remote shutdown switch or circuit breaker shall be located just outside the boiler room door and marked for easy identification. Consideration should also be given to the type and location of the switch to safeguard against tampering.
c) A disconnecting means capable of being locked in the open position shall be installed at an accessible location at the boiler so that the boiler can be disconnected from all sources of potential. This disconnecting means shall be an integral part of the boiler or adjacent to it.
d) If the boiler room door is on the building exterior, the switch shall be located just inside the door. If there is more than one door to the boiler room, there shall be a switch located at each door of egress.
1) For atmospheric-gas burners, and oil burners where a fan is on a common shaft with the oil pump, the complete burner and controls should be shut off.
2) For power burners with detached auxiliaries, only the fuel input supply to the firebox need be shut off.
e) Controls and Heat Generating Apparatus
1) Oil- and gas-fired and electrically heated boilers and water heaters shall be equipped with suitable primary (flame safeguard) safety controls, safety limit controls, and burners or electric elements as required by a nationally or internationally recognized standard.
2) The symbol of the certifying organization that has investigated such equipment as having complied with a nationally recognized standard shall be affixed to the equipment and shall be considered as evidence that the unit was manufactured in accordance with that standard.
3) These devices shall be installed in accordance with jurisdictional and environmental requirements, manufacturer’s recommendations, and/or industry standards, as applicable.
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NB14‐0401
b) Statement of Need
Provide a brief explanation of the need for the revision or addition.
c) Background Information
Provide background information to support the revision or addition, including any data or changes in
technology that form the basis for the request that will allow the Committee to adequately evaluate the
proposed revision or addition. Sketches, tables, figures, and graphs should be submitted as appropriate.
When applicable, identify any pertinent paragraph in the Code that would be affected by the revision or
addition and identify paragraphs in the Code that reference the paragraphs that are to be revised or
added.
Part 1 Installation does not require lockable disconnects. Wording needs to be added to become more
uniform with other codes and standards
Other codes and standard require lockable disconnects on power, heating and hot water supply boilers thus
changes need to be made to Part 1 Installation to address the disconnects. See the first section above.
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Definition of the term Equipment for Part 1 Installation where applicable.
Suggestion:
Equipment Room – means a room or space within a building for the installation of mechanical or
electrical/electronic devices. It includes but is not limited to equipment such as boilers used in their
applications. In some cases, this room is also called a boiler or machinery room.
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2013 NATIONAL BOARD INSPECTION CODE
2 PART 1 — INSTALLATION
Part 1 — InstallatIon table of Contents
National Board Contact Information ....................................................................................................... II
NB Board of Trustees / Advisory Committee Members........................................................................... III
National Board Members ..................................................................................................................... IV
NBIC Committee Structure .................................................................................................................... V
National Board Inspection Code Edition / Addendum ............................................................................ XI
Foreword ............................................................................................................................................ XII
Introduction ........................................................................................................................................ XIV
Section 1 General Guidelines ......................................................................................................... 7 1.1 Introduction ............................................................................................... 8 1.2 Purpose ..................................................................................................... 8 1.3 Application of these Rules ............................................................................ 8
1.4 Certification, Inspection, and Jurisdictional Requirements ............................................... 9 1.4.1 Responsibility .................................................................................................................... 9
1.4.2 Equipment Certification ................................................................................ 9 1.4.3 Jurisdictional Review .................................................................................... 9 1.4.4 Inspection ................................................................................................... 10 1.4.5 Boiler Installation Report ............................................................................... 10
1.4.5.1 Boiler Installation Report I-1 .......................................................................................... 11 1.4.5.1.1 Guide for Completing National Board Boiler Installation Report ........................................ 12
Section 2 Power Boilers ................................................................................................................ 15 2.1 Scope ............................................................................................................................ 16
2.2 Definitions ............................................................................................... 16 2.3 General Requirements ............................................................................ 16
2.3.1 Supports, Foundations, and Settings ........................................................... 16 2.3.2 Structural Steel ........................................................................................... 16 2.3.3 Clearances ................................................................................................... 16
2.4 Boiler RoomEquipment room Requirements............................................ 17 2.4.1 Exit ............................................................................................................. 17 2.4.2 Ladders and Runways .................................................................................. 17 2.4.3 Drains ........................................................................................................... 18 2.4.4 Water (Cleaning) ......................................................................................... 18
2.5 Source Requirements .............................................................................. 18 2.5.1 Feedwater .................................................................................................. 18
2.5.1.1 Volume ................................................................................................................. 18 2.5.1.2 Connection ...................................................................................................... 18 2.5.1.3 Pumps ........................................................................................................... 19 2.5.1.4 Valves ...................................................................................................................... 19
2.5.2 Fuel ............................................................................................................ 20 2.5.3 Electrical ..................................................................................................... 20
2.5.3.1 Wiring ............................................................................................................ 20 2.5.3.2 Remote Emergency Shutdown Switches ....................................................... 20 2.5.3.3 Controls and Heat-Generating Apparatus ....................................................... 21
2.5.4 Ventilation and Combustion Air .................................................................... 21 2.5.5 Lighting ......................................................................................................... 21 2.5.6 Emergency Valves and Controls ................................................................... 22
2.6 Discharge Requirements ......................................................................... 22
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PART 1 — INSTALLATION 3
2.6.1 Chimney or Stack ........................................................................................ 22 2.6.2 Ash Removal ................................................................................................ 22 2.6.3 Drains ........................................................................................................... 22
2.6.3.1 Connection ...................................................................................................... 22 2.6.3.2 Pressure Rating ............................................................................................... 22 2.6.3.3 Parts .............................................................................................................. 23
2.7 Operating Systems .................................................................................. 23 2.7.1 Breeching and Dampers ............................................................................... 23 2.7.2 Burners and Stokers ................................................................................... 23 2.7.3 Steam Supply ............................................................................................. 23 2.7.4 Condensate and Return ................................................................................ 24 2.7.5 Blowoff .......................................................................................................... 24
2.8 Controls and Gages ................................................................................. 26 2.8.1 Water ................................................................................................................. 26 2.8.2 Pressure Gage ........................................................................................... 27
2.8.2.1 Connection ...................................................................................................... 27 2.8.3 Temperature ...................................................................................................... 27
2.9 Pressure Relief Valves ..................................................................................... 27 2.9.1 Valve Requirements — General .................................................................. 27
2.9.1.1 Number ............................................................................................................ 28 2.9.1.2 Location ........................................................................................................... 28 2.9.1.3 Capacity ........................................................................................................... 28 2.9.1.4 Set Pressure .................................................................................................. 30
2.9.2 Forced-Flow Steam Generator ................................................................... 30 2.9.3 Superheaters .............................................................................................. 31 2.9.4 Economizers .............................................................................................. 31 2.9.5 Pressure-Reducing Valves ................................................................................ 31
2.9.6 Mounting and Discharge Requirements ........................................................................ 32 2.10 Testing and Acceptance ............................................................................. 33
2.10.1 General ........................................................................................................ 33 2.10.2 Pressure Test ................................................................................................................. 33 2.10.3 Nondestructive Examination ......................................................................... 33 2.10.4 System Testing ...................................................................................................... 34 2.10.5 Final Acceptance .......................................................................................... 34 2.10.6 Boiler Installation Report................................................................................. 34
2.11 Tables and Figures ..................................................................................... 34
Section 3 Steam Heating Boilers, Hot-Water Heating Boilers, Hot-Water Supply Boilers, and Potable Water Heaters ................................................................................. 35
3.1 Scope ............................................................................................................................ 36 3.2 Definitions ............................................................................................... 36 3.3 General Requirements ............................................................................ 36
3.3.1 Supports ..................................................................................................... 36 3.3.1.1 Methods of Support for Steam Heating, Hot-Water Heating,
and Hot-Water Supply Boilers ........................................................................................ 36 3.3.2 Settings ...................................................................................................... 38 3.3.3 Structural Steel ........................................................................................... 38 3.3.4 Clearances ................................................................................................... 38
3.4 Boiler RoomEquipment room Requirements............................................ 39 3.4.1 Exit ............................................................................................................. 39 3.4.2 Ladders and Runways .................................................................................. 39
3.5 Source Requirements .............................................................................. 40 3.5.1 Water ................................................................................................................. 40 3.5.2 Fuel ............................................................................................................ 40 3.5.3 Electrical ..................................................................................................... 40 3.5.4 Ventilation and Combustion Air .................................................................... 41 3.5.5 Lighting ......................................................................................................... 41 3.5.6 Emergency Valves and Controls ................................................................... 41
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c) Boilers with a top-opening manhole shall have at least 84 in. (2135 mm) of unobstructed clearance above the manhole to the ceiling of the boiler roomequipment room.
d) Boilers without top-opening manholes shall have at least 36 in. (915 mm) of clearance from the top of the
boiler or as recommended by the manufacturer.
e) Boilers with a bottom opening used for inspection or maintenance shall have at least 12 in. (305 mm) of unobstructed clearance.
2.4 boIler roomequipment room requIrements
2.4.1 exIt
Two means of exit shall be provided for boiler roomequipment rooms exceeding 500 sq. ft. (46.5 sq. m) floor area and contain- ing one or more boilers having a combined fuel capacity of 1,000,000 Btu/hr (293 kW) or more. Each elevation shall be provided with at least two means of exit, each to be remotely located from the other. A platform at the top of a single boiler is not considered an elevation.
2.4.2 ladders and runways
a) All walkways, runways, and platforms shall be:
1) of metal construction;
2) provided between or over the top of boilers that are more than 8 ft. (2.4 m) above the operating floor
to afford accessibility for normal operation, maintenance, and inspection;
3) constructed of safety treads, standard grating, or similar material and have a minimum width of 30 in. (760 mm);
4) of bolted, welded, or riveted construction;
5) equipped with handrails 42 in. (1070 mm) high with an intermediate rail and 4 in. (100 mm) toe-board.
b) Stairways that serve as a means of access to walkways, runways, or platforms shall not exceed an angle
of 45 degrees from the horizontal and shall be equipped with handrails 42 in. (1070 mm) high with an intermediate rail.
c) Ladders that serve as a means of access to walkways, runways, or platforms shall:
1) be of metal construction and not less than 18 in. (460 mm) wide;
2) have rungs that extend through the side members and are permanently secured;
3) have a clearance of not less than 30 in. (760 mm) from the front of rungs to the nearest permanent
object on the climbing side of the ladder;
4) have a clearance of not less than 6-1/2 in. (165 mm) from the back of rungs to the nearest permanent object;
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5) have a clearance width of at least 15 in. (380 mm) from the center of the ladder on either side across the front of the ladder.
d) There shall be at least two permanently installed means of exit from walkways, runways, or platforms that
exceed 6 ft. (1.8 m) in length.
2.4.3 draIns
At least one floor drain shall be installed in the boiler roomequipment room.
2.4.4 water (CleanIng)
A convenient water supply shall be provided for flushing out the boiler and its appurtenances, adding water to the boiler while it is not under pressure, and cleaning the boiler roomequipment room floor.
2.5 sourCe requIrements
2.5.1 feedwater
2.5.1.1 volume
The source of feedwater shall be capable of supplying a sufficient volume of water as determined by the boiler manufacturer in order to prevent damage to the boiler when all the safety relief valves are discharging at full capacity.
2.5.1.2 ConneCtIon
a) To prevent thermal shock, feedwater shall be introduced into a boiler in such a manner that the water will
not be discharged directly against surfaces exposed to high temperature gases or to direct radiation from the flame.
b) For boiler operating pressures of 400 psig (2.8 MPa) or higher, the feedwater inlet through the drum shall
be fitted with shields, sleeves, or other suitable means to reduce the effects of temperature differentials in the shell or head.
c) Feedwater other than condensate return shall not be introduced through the blowoff.
d) Boilers having more than 500 sq. ft. (46.5 sq. m) of water heating surface shall have at least two means of
supplying feedwater. For boilers that are fired with solid fuel not in suspension, and boilers whose setting or heat source can continue to supply sufficient heat to cause damage to the boiler if the feedwater supply is interrupted, one such means of supplying feedwater shall not be subject to the same interruption as the first method. Boilers fired by gaseous, liquid, or solid fuel in suspension may be equipped with a single means of supplying feedwater, provided means are furnished for the immediate removal of heat input if the supply of feedwater is interrupted.
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d) On single boiler-turbine unit installations, the boiler feedwater stop valve may be located upstream from the boiler feedwater check valve.
e) If a boiler is equipped with duplicate feedwater supply arrangements, each such arrangement shall be
equipped as required by these rules.
f) A check valve shall not be a substitute for a stop valve.
g) A combination feedwater stop-and-check valve in which there is only one seat and disk and a valve stem is provided to close the valve when the stem is screwed down shall be considered only as a stop valve, a separate check valve shall be installed.
h) Whenever globe valves are used on feedwater piping, the inlet shall be under the disk of the valve.
i) Stop valves and check valves shall be placed on the inlet of economizers or feedwater-heating devices.
j) The recirculating return line for a high-temperature water boiler shall be provided with the stop valve, or
valves, required for the main discharge outlet on the boiler.
2.5.2 fuel
Fuel systems, whether firing coal, oil, gas, or other substance, shall be installed in accordance with jurisdictional and environmental requirements, manufacturer’s recommendations, and/or industry standards, as applicable.
2.5.3 eleCtrICal
2.5.3.1 wIrIng
All wiring for controls, heat generating apparatus, and other appurtenances necessary for the operation of the boiler or boilers should be installed in accordance with the provisions of national or international standards and comply with the applicable local electrical codes.
2.5.3.2 remote emergenCy shutdown swItChes
a) A manually operated remote shutdown switch or circuit breaker shall be located just outside the boiler roomequipment room door and marked for easy identification. Consideration should also be given to the type and location of the switch in order to safeguard against tampering.
b) For boiler roomequipment rooms exceeding 500 sq. ft. (46.5 sq. m) floor area or containing one or
more boilers having a combined fuel capacity of 1,000,000 Btu/hr (293kW) or more, additional manually operated remote emergency shutdown switches shall be located at suitably identified points of egress acceptable to the Jurisdiction.
c) Where a boiler is located indoors in a facility and not in a boiler roomequipment room, a remote
emergency shutdown switch shall be located within 50 feet of the boiler along the primary egress route from the boiler area.
d) Consideration should be given to the type and location of the remote emergency shutdown switch(es) in
order to safeguard against tampering. Where approved by the Jurisdiction, alternate locations of remote emergency switch(es) may be provided.
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e) For atmospheric-gas burners and for oil burners where a fan is on the common shaft with the oil pump, the emergency remote shutdown switch(es) or circuit breaker(s) must disconnect all power to the burner controls.
f) For power burners with detached auxiliaries, the emergency remote shutdown switch(es) or circuit breaker(s)
need only shut off the fuel input to the burner.
2.5.3.3 Controls and heat-generatIng aPParatus
a) Oil and gas-fired and electrically heated boilers shall be equipped with suitable primary (flame safeguard)
safety controls, safety limit switches and controls, and burners or electric elements as required by a na- tionally or internationally recognized standard.
b) The symbol of the certifying organization that has investigated such equipment as having complied with
a nationally recognized standard shall be affixed to the equipment and shall be considered as evidence that the unit was manufactured in accordance with that standard.
c) These devices shall be installed in accordance with jurisdictional and environmental requirements, manu-
facturer’s recommendations, and/or industry standards, as applicable.
2.5.4 ventIlatIon and CombustIon aIr
a) The boiler roomequipment room shall have an adequate air supply to permit clean, safe combustion,
minimize soot forma- tion, and maintain a minimum of 19.5% oxygen in the air of the boiler roomequipment room. The combustion and ventilation air should be supplied by either an unobstructed air opening or by power ventilation or fans.1
b) Unobstructed air openings shall be sized on the basis of 1 sq. in. (650 sq. mm) free area per 2000 Btu/ hr (586 W) maximum fuel input of the combined burners located in the boiler roomequipment room, or as specified in the National Fire Protection Association (NFPA) standards for oil and gas burning installations for the particular job conditions. The boiler roomequipment room air supply openings shall be kept clear at all times.
c) Power ventilators or fans shall be sized on the basis of 0.2 cfm (0.0057 cu meters per minute) for each
1000 Btu/hr (293 W) of maximum fuel input for the combined burners of all boilers located in the boiler roomequipment room. Additional capacity may be required for any other fuel-burning equipment in the boiler roomequipment room.
d) When power ventilators or fans are used to supply combustion air, they shall be installed with interlock
devices so that the burners will not operate without an adequate number of ventilators/fans in operation.
e) The size of openings specified in NBIC Part 1, 2.5.4 b) may be reduced when special engineered air sup- ply systems approved by the Jurisdiction are used.
f) Care should be taken to ensure that steam and water lines are not routed across combustion air openings,
where freezing may occur in cold climates.
2.5.5 lIghtIng
The boiler roomequipment room should be well lighted and it should have an emergency light source for use in case of power failure.
1 Fans – When combustion air is supplied to the boiler by an independent duct, with or without the employment of power ventilators or fans, the duct shall be sized and installed in accordance with the manufacturer’s recommendations. However, ventilation for the boiler Page 30 of 92
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roomequipment room must still be considered.
PART 1 — INSTALLATION SECTION 2 21
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b) Modular heating boilers that require individual units to be set side by side, front to back, or by stacking shall provide clearances in accordance with the manufacturer’s recommendations, subject to acceptance by the Jurisdiction.
c) Heating boilers shall be located so that adequate space is provided for proper operation, maintenance,3
and inspection of equipment and appurtenances.
3.4 boIler roomequipment room requIrements
3.4.1 exIt
Two means of exit shall be provided for boiler roomequipment rooms exceeding 500 sq. ft. (46.5 sq. m) of floor area and contain- ing one or more boilers having a combined fuel capacity of 1,000,000 Btu/hr (293 kW) or more (or equivalent electrical heat input). Each elevation shall be provided with at least two means of exit, each to be remotely located from the other. A platform at the top of a single boiler is not considered an elevation.
3.4.2 ladders and runways
a) All walkways, runways, and platforms shall be:
1) of metal construction;
2) provided between or over the top of boilers that are more than 8 ft. (2.4 m) above the operating floor
to afford accessibility for normal operation, maintenance, and inspection;
3) constructed of safety treads, standard grating, or similar material and have a minimum width of 30 in. (760 mm);
4) of bolted, welded, or riveted construction; and
5) equipped with handrails 42 in. (1070 mm) high with an intermediate rail and 4 in. (100 mm) toe board.
b) Stairways that serve as a means of access to walkways, runways, or platforms shall not exceed an angle
of 45 degrees from the horizontal and be equipped with handrails 42 in. (1070 mm) high with an intermedi- ate rail.
c) Ladders that serve as a means of access to walkways, runways, or platforms shall:
1) be of metal construction and not less than 18 in. (460 mm) wide;
2) have rungs that extend through the side members and are permanently secured;
3) have a clearance of not less than 30 in. (760 mm) from the front of rungs to the nearest permanent
object on the climbing side of the ladder;
4) have a clearance of not less than 6-1/2 in. (165 mm) from the back of rungs to the nearest permanent object; and
3 Maintenance – This includes the removal of tubes.
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5) have a clearance width of at least 15 in. (380 mm) from the center of the ladder on either side across the front of the ladder.
d) There shall be at least two permanently installed means of exit from walkways, runways, or platforms that
exceed 6 ft. (1.8 m) in length.
3.5 sourCe requIrements
3.5.1 water
a) A means to add water to or fill the boiler, while not under pressure, shall be provided. A valve or threaded
plug may be used to shut off the fill connection when the boiler is in service.
b) Water fill connections shall be installed. A means shall be provided at or near the boiler to prevent back- feeding. Such means shall be rated for the boiler design pressure and temperature.
c) Provision should also be made in every boiler roomequipment room for a convenient water supply that can be used to
flush out the boiler and to clean the boiler roomequipment room floor.
3.5.2 fuel
Fuel systems, whether firing coal, oil, gas, or other substance, shall be installed in accordance with jurisdictional and environmental requirements, manufacturer’s recommendations, and/or industry standards, as applicable.
3.5.3 eleCtrICal
a) All wiring for controls, heat generating apparatus, and other appurtenances necessary for the operation
of the boiler or boilers shall be installed in accordance with the provisions of national or international stan- dards and comply with the applicable local electrical codes.
b) A manually operated remote shutdown switch or circuit breaker shall be located just outside the boiler
roomequipment room door and marked for easy identification. Consideration should also be given to the type and location of the switch to safeguard against tampering.
c) If the boiler roomequipment room door is on the building exterior, the switch shall be located just inside
the door. If there is more than one door to the boiler roomequipment room, there shall be a switch located at each door of egress.
1) For atmospheric-gas burners, and oil burners where a fan is on a common shaft with the oil pump,
the complete burner and controls should be shut off.
2) For power burners with detached auxiliaries, only the fuel input supply to the firebox need be shut off.
d) Controls and Heat Generating Apparatus
1) Oil- and gas-fired and electrically heated boilers and water heaters shall be equipped with suitable primary (flame safeguard) safety controls, safety limit controls, and burners or electric elements as required by a nationally or internationally recognized standard.
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2) The symbol of the certifying organization that has investigated such equipment as having complied with a nationally recognized standard shall be affixed to the equipment and shall be considered as evidence that the unit was manufactured in accordance with that standard.
3) These devices shall be installed in accordance with jurisdictional and environmental requirements,
manufacturer’s recommendations, and/or industry standards, as applicable.
3.5.4 ventIlatIon and CombustIon aIr
a) The boiler roomequipment room shall have an adequate air supply to permit clean, safe combustion,
minimize soot forma- tion, and maintain a minimum of 19.5% oxygen in the air of the boiler roomequipment room. The combustion and ventilation air may be supplied by either an unobstructed air opening or by power ventilation or fans.4
b) Unobstructed air openings shall be sized on the basis of 1 sq. in. (645 sq mm) free area per 2000 Btu/
hr (586 W) maximum fuel input of the combined burners located in the boiler roomequipment room, or as specified in the National Fire Protection Association (NFPA) standards for oil and gas burning installations for the particular job conditions. The boiler roomequipment room air supply openings shall be kept clear at all times.
c) Power ventilators or fans shall be sized on the basis of 0.2 cfm (.0057 cu meters per minute) for each
1,000 Btu/hr (293 W) of maximum fuel input for the combined burners of all boilers and/or water heaters located in the boiler roomequipment room. Additional capacity may be required for any other fuel burning equipment in the boiler roomequipment room.
d) When power ventilators or fans are used to supply combustion air, they shall be installed with interlock devices so that the burners will not operate without an adequate number of ventilators/fans in operation.
e) When combustion air is supplied to the heating boiler by an independent duct, with or without the employ-
ment of power ventilators or fans, the duct shall be sized and installed in accordance with the manufac- turer’s recommendations. However, ventilation for the boiler roomequipment room must still be considered.
f) The size of openings specified in NBIC Part 1, 3.5.4 b) may be reduced when special engineered air sup- ply systems approved by the Jurisdiction are used.
g) Care should be taken to ensure that steam and water lines are not routed across combustion air openings,
where freezing may occur in cold climates.
3.5.5 lIghtIng
The boiler roomequipment room should be well lighted, and it should have an emergency light source for use in case of power failure.
3.5.6 emergenCy valves and Controls
All emergency shut-off valves and controls shall be accessible from a floor, platform, walkway or runway. Ac- cessibility shall mean within a 6 ft. (1.8 m) elevation of the standing space and not more than 12 in. (305 mm) horizontally from the standing space edge.
4 Fans – When combustion air is supplied to the boiler by an independent duct, with or without the employment of power ventilators or fans, the duct shall be sized and installed in accordance with the manufacturer’s recommendations. However, ventilation for the boiler roomequipment room must still be considered.
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3.6 dIsCharge requIrements
3.6.1 ChImney or staCk
Chimneys or stacks shall be installed in accordance with jurisdictional and environmental requirements, manu- facturer’s recommendations, and/or industry standards, as applicable.
3.6.2 ash removal
Ash removal systems shall be installed in accordance with jurisdictional and environmental requirements, manufacturer’s recommendations, and/or industry standards, as applicable.
3.6.3 draIns
Unobstructed floor drains, properly located in the boiler roomequipment room, will facilitate proper cleaning of the boiler roomequipment room. Floor drains that are used infrequently should have water poured into them periodically to prevent the entrance of sewer gasses and odors. If there is a possibility of freezing, an environmentally safe antifreeze mixture should be used in the drain traps. Drains receiving blowdown water should be connected to the sanitary sewer by way of an acceptable blowdown tank or separator or an air gap that will allow the blowdown water to cool to at least 140°F (60°C) and reduce the pressure to 5 psig (34 kPa) or less.
3.7 oPeratIng systems
3.7.1 oIl heaters
a) A heater for oil or other liquid harmful to boiler operation shall not be installed directly in the steam or water
space within a boiler.
b) Where an external-type heater for such service is used, means shall be provided to prevent the introduction into the boiler of oil or other liquid harmful to boiler operation.
3.7.2 breeChIng and damPers
Breeching and dampers shall be installed in accordance with jurisdictional and environmental requirements, manufacturer’s recommendations, and/or industry standards, as applicable.
3.7.3 burners and stokers
Burners and stokers shall be installed in accordance with jurisdictional and environmental requirements, manufacturer’s recommendations, and/or industry standards, as applicable.
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b boilers — Part 2 (2.2), (2.5.5.1)
watertube — Part 2 (2.2.12.1) black liquor — Part 2 - (2.2.12.2) organic and Inorganic fluid — Part 2 (2.2.12.3) waste heat — Part 2 (2.2.12.4) Cast Iron — Part 2 (2.2.12.5) electric — Part 2 (2.2.12.6) fired-storage water heaters — Part 2 (2.2.12.8) firetube — Part 2 (2.2.12.9) historical/hobby — Part 2 (Supplement 2) modular — Part 1 (3.7.8) locomotive — Part 2 (Supplement 1)
boiler Inspection guideline (historical) — Part 2 (S2.11)
boiler Installation,
Power boilers — Part 1 (Section 2) steam heating — Part 1 (Section 3) heating/Potable water heaters — Part 1 (Section 3) report — Part 1 (1.4.5), (2.10.6), (3.10.3)
boiler operators (historical) — Part 2 (S2.11)
boiler repair — Part 3 (3.3.4.2), (3.3.4.3), (Supplement 1),
(Supplement 2)
boiler relief devices — Part 2 (2.5.5.1)
boiler roomequipment room requirements — Part 1 (2.4), (3.4)
bonding — Part 3 (S4.10)
blowoff — Part 1 (2.7.5), (3.7.7); Part 2 (2.2.6)
braces — Part 3 (S1.2.6); Part 2 (S1.4.2)
brittle fracture — Part 2 (5.3.8.2)
bulges and blisters — Part 2 (3.4.7), (5.3.8.3), (S7.8.3);
Part 3 (3.3.4.2)
burners and stokers — Part 1 (2.7.2), (3.7.3)
C Calculations — Part 1 (7.3); Part 2 (S2.10.1), (S2.6.2), (7.3);
Part 3 (3.2.4), (3.2.5), (3.3.3), (3.3.4.3), (3.4.1), (3.4.2), (S1.1.4), (S4.6), (S4.16.3), (S4.17.4), (S4.17.5), (S4.18.2.3)
Capacity — Part 1 (2.9.1.3), (5.3.4); Part 2 (2.3.6.2),
(2.5.2), (2.5.4), (2.5.5.3), (2.5.7), (S2.8.1), (S2.11), (S5.3.1), (S5.9.3), (S6.8), (S6.13.9), (S6.13.11.3), (S6.13.11.4), (S6.15.1), (S6.15.4)
Cargo tanks — Part 2 (Supplement 6)
Capacity Certification — Part 1, Part 2 and Part 3 (5.9.3), (Section 9)
Caulking riveted seams — Part 3 (S1.2.12.1), (S2.13.13.1)
PART 1 — INSTALLATION SECTION 11 131Page 36 of 92
Action Item Request Form
8.3 CODE REVISIONS OR ADDITIONS
Request for Code revisions or additions shall provide the following:
a) Proposed Revisions or Additions
For revisions, identify the rules of the Code that require revision and submit a copy of the appropriate
rules as they appear in the Code, marked up with the proposed revision. For additions, provide the
recommended wording referenced to the existing Code rules.
Existing Text:
b) Statement of Need
Provide a brief explanation of the need for the revision or addition.
Part 1 – Section 2
2.7.3 Steam Supply
f) Ample provision for gravity drain shall be provided when a stop valve is so located that water or condensation may
accumulate. The gravity drain(s) shall be located such that the entire steam supply system can be drained.
2.9.6 M ounting and Discharge Requirements
h) All safety or safety relief valves shall be piped to a safe point of discharge so located or piped as to be carried clear
from running boards or platforms. Ample provision for gravity drain shall be made in the discharge pipe at or near each
safety or safety relief valve, and where water or condensation may collect. Each valve shall have an open gravity drain
through the casing below the level of the valve seat. For iron and steel‐ bodied valves exceeding NPS 2 (DN 50), the drain
hole shall be tapped not less than NPS 3/8 (DN 10).
It is the "gravity drain" that shall be ample not the "provision". This is also consistent with ASME
language in Section I and language adopted by SG Historical Boilers.
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c) Background Information
Provide background information to support the revision or addition, including any data or changes in
technology that form the basis for the request that will allow the Committee to adequately evaluate the
proposed revision or addition. Sketches, tables, figures, and graphs should be submitted as appropriate.
When applicable, identify any pertinent paragraph in the Code that would be affected by the revision or
addition and identify paragraphs in the Code that reference the paragraphs that are to be revised or
added.
ASME Section I PG‐58.3.2 When two or more boilers are connected to a common steam header, or when a
single boiler is connected to a header having another steam source (e.g., a turbine extraction line), the
connection from each boiler having a manhole opening shall be fitted with two stop valves having an ample
free‐blow drain between them.
The proposed change will make the NBIC consistent with ASME Section I.
Page 38 of 92
Changes suggested Part 1 Section 2.7.3 Steam Supply f) Ample provisionProvision for an ample gravity drain shall be provided when a stop valve is so located that water or condensation may accumulate. The gravity drain(s) shall be located such that the entire steam supply system can be drained. 2.9.6 Mounting and Discharge Requirements h) All safety or safety relief valves shall be piped to a safe point of discharge so located or piped as to be carried clear from running boards or platforms. Ample provisionProvision for an ample gravity drain shall be made in the discharge pipe at or near each safety or safety relief valve, and where water or condensation may collect. Each valve shall have an open gravity drain through the casing below the level of the valve seat. For iron and steel- bodied valves exceeding NPS 2 (DN 50), the drain hole shall be tapped not less than NPS 3/8 (DN 10).
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1
Subject: Part 2, Supplement 2, S2.6.2 – Ultrasonic Thickness Testing
File Number: NB11-1101
Proposal: Add more information for the evaluation of local pitting corrosion versus general corrosion.
Explanation:
a) Add a new section S2.6.3 to better define the evaluation of corrosion and the effects on MAWP.
b) Remove Note b) from S2.6.2
New Proposed text for S2.6.3
S2.6.3 Evaluation of corrosion
S2.6.3.1 Line and Crevice Corrosion
Line and Crevice corrosion may be disregarded for MAWP calculations when:
a) The thickness of the remaining material is at least 75% of the required thickness per the MAWP calculations.
b) The total length does not exceed 2 inches (50 mm).
S2.6.3.2 Widely Scattered Pits
Widely scattered corrosion pits may be disregarded for MAWP calculations when: a) The depths of the pits are such that the remaining material shall not be less than 50%
of the required thickness per the MAWP calculations. b) The total area of pits, below the required thickness per the MAWP calculations, does
not exceed 7 sq. inches (4500 sq. mm) within any 50 sq. inches (32000 sq. mm) area. c) Total length of pits in an 8 inch (200 mm) straight line cannot exceed 2 inches (50
mm).
S2.6.3.3 Locally Thinned Areas
Locally thinned areas (LTA), 3 inch (75 mm) in diameter or less, may be disregarded for MAWP calculations when:
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a) The average depth of the corrosion is such that remaining material shall not be less than 75% of the required thickness per the MAWP calculations.
b) The thickness at the thinnest point shall not be less than 50% of the required thickness per the MAWP calculations.
c) The minimum distance between the boundaries of two locally thinned areas (MDLTA) must be greater than the average diameters of the two locally thinned areas (LTA) multiplied by 3.0. See Figure S2.6.3.3
S2.6.3.4 Generalized Thinned Areas
For corroded area’s exceeding the specifications in S2.6.3.1, S2.6.3.2, and S2.6.3.3, the thickness may be averaged over an area not exceeding the UT grid size specified in S2.6.2 c) and S2.6.2 d). The thickness at the thinnest point shall not be less than 50% of the required thickness per the MAWP calculations and the average shall not be less than 75% of the required thickness per the MAWP calculations.
When general corrosion is identified the exceeds the limits set forth in this paragraph the pressure vessel MAWP shall be de-rated to meet these requirements, or removed from service until it is repaired by a qualified organization.
Note: These guidelines in S2.6.3.1, S2.6.3.2, S2.6.3.3 and S2.6.3.4 are to be used in areas of thinning due to corrosion. Area’s where plates have been formed to make corners and radius will be thinned due to the forming process and should not be taken into account when calculating MAWP.
Figure S2.6.3.3 Locally Thinned Areas
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Proposed changes to text for S2.6.2
Remove this text (b) from S2.6.2
Page 42 of 92
CURRENT WORDING – NBIC Part 2, SECTION 5 5.2 – 5.3.1 5.2 REPLACEMENT OF STAMPING DURING INSERVICE INSPECTION
5.2.1 AUTHORIZATION
a) When the stamping on a pressure‐retaining item becomes indistinct or the nameplate is lost, illegible, or detached, but traceability to the original pressure‐retaining item is still possible, the Inspector shall instruct the owner or user to have the stamped data replaced. All re‐stamping shall be done in accordance with the original code of construction, except as modified herein. Requests for permission to re‐stamp or replace nameplates shall be made to the Jurisdiction in which the pressure‐retaining item is installed. Application must be made on the Replacement of Stamped Data Form, NB‐136 (see 5.3.2). Proof of the original stamping and other such data, as is available shall be furnished with the request. Permission from the Jurisdiction is not required for the reattachment of nameplates that are partially attached. When traceability cannot be established, the Jurisdiction shall be contacted.
b) When there is no Jurisdiction, the replacement of stamped data shall be authorized and
witnessed by a National Board Commissioned Inspector and the completed Form NB‐136 (see 5.3.2) shall be submitted to the National Board.
5.2.2 REPLACEMENT OF STAMPED DATA a) The re‐stamping or replacement of data shall be witnessed by a National Board Commissioned
Inspector and shall be identical to the original stamping.
b) The Re‐stamping or replacement of a code symbol stamp shall be performed only as permitted by the governing code of construction.
c) Replacement nameplates shall be clearly marked “replacement”.
5.2.3 REPORTING Form NB‐136 shall be filed with The National Board by the “R” Stamp holder, bearing a facsimile of
the replacement stamping or nameplate, as applied, and shall also bear the signatures of the Authorizing Jurisdiction, the National Board Commissioned Inspector who witnessed the replacement, and the “R” Stamp holder that performed the replacement. Form NB‐136 shall filed with their Local Jurisdiction (if required) by the owner or user.
5.3 NATIONAL BOARD INSPECTION FORMS
5.3.1 SCOPE
The following forms may be used for documenting specific requirements as indicated on the top of
each form.
Note: Jurisdictions may have adopted other forms and may not accept these forms.
Page 43 of 92
PROPOSED CHANGES – NBIC Part 2, SECTION 5 5.2 – 5.3.1 5.2 REPLACEMENT OF STAMPING OR NAMEPLATE DURING INSERVICE INSPECTION
5.2.1 AUTHORIZATION a) When the stamping on a pressure‐retaining item becomes indistinct or the nameplate is lost,
illegible, or detached, but traceability to the original pressure‐retaining item is still possible, the Inspector shall instruct the owner or user to have the nameplate or stamped data replaced. All re‐stamping shall be done in accordance with the original code of construction, except as modified herein. Requests for permission to re‐stamp or replace nameplates shall be made to the Jurisdiction in which the pressure‐retaining item is installed. nameplate or stamping is re‐applied. Application must be made on the Replacement of Stamped Data Form, NB‐136 (see 5.3.2). Proof of traceability to the original nameplate or stamping, and other such data, as is available, shall be furnished with the request. Permission from the Jurisdiction is not required for the reattachment of nameplates that are partially attached. When traceability cannot be established, the Jurisdiction shall be contacted. The completed Form NB‐136 (see 5.3.2) shall be submitted to the National Board.
b) When there is no Jurisdiction, the traceability shall be accepted and the replacement of the
nameplate or stamped data shall be authorized and witnessed by a National Board Commissioned Inspector. and tThe completed Form NB‐136 (see 5.3.2) shall be submitted to the National Board.
5.2.2 REPLACEMENT OF NAMEPLATE OR STAMPED DATA a) The re‐stamping or replacement of data shall be witnessed by a National Board Commissioned
Inspector. and shall be identical to the original stamping.
b) The Re‐stamping or replacement of a code symbol stamp shall be performed only as permitted by the governing code of construction.
c) Replacement nameplates shall be clearly marked “replacement”.
5.2.3 REPORTING Form NB‐136 shall be filed with the Jurisdiction by the owner or user (if required) or and tThe
National Board by the “R” Stamp Holder owner or user together with bearing a facsimile of the replacement stamping or nameplate, as applied, and shall also bear the signature of the “R” Stamp holder that performed the replacement and the National Board Commissioned Inspector who authorized and witnessed the replacement.
5.3 NATIONAL BOARD INSPECTION FORMS
5.3.1 SCOPE
The following forms (5.3.2 through 5.3.7.1) may be used for documenting specific requirements as
indicated on the top of each form.
Note: Jurisdictions may have adopted other forms and may not accept these forms.
Page 44 of 92
PROPOSED WORDING – NBIC Part 2, SECTION 5 5.2 – 5.3.1 5.2 REPLACEMENT OF STAMPING OR NAMEPLATE 5.2.1 AUTHORIZATION
a) When the stamping on a pressure‐retaining item becomes indistinct or the nameplate is lost, illegible, or detached, but traceability to the original pressure‐retaining item is still possible, the Inspector shall instruct the owner or user to have the nameplate or stamped data replaced. All re‐stamping shall be done in accordance with the original code of construction, except as modified herein. Requests for permission to re‐stamp or replace nameplates shall be made to the Jurisdiction in which the nameplate or stamping is re‐applied. Application must be made on the Replacement of Stamped Data Form, NB‐136 (see 5.3.2). Proof of traceability to the original nameplate or stamping, and other such data as is available, shall be furnished with the request. Permission from the Jurisdiction is not required for the reattachment of nameplates that are partially attached. When traceability cannot be established, the Jurisdiction shall be contacted. The completed Form NB‐136 (see 5.3.2) shall be submitted to the National Board.
b) When there is no Jurisdiction, the traceability shall be accepted and the replacement of the
nameplate or stamped data shall be authorized and witnessed by a National Board Commissioned Inspector. The completed Form NB‐136 (see 5.3.2) shall be submitted to the National Board.
5.2.2 REPLACEMENT OF NAMEPLATE OR STAMPED DATA a) The re‐stamping or replacement of data shall be witnessed by a National Board Commissioned
Inspector. b) The Re‐stamping or replacement of a code symbol stamp shall be performed only as permitted
by the governing code of construction. c) Replacement nameplates shall be clearly marked “replacement”.
5.2.3 REPORTING Form NB‐136 shall be filed with the Jurisdiction by the owner or user (if required) and the National
Board by the “R” Certificate Holder bearing a facsimile of the replacement stamping or nameplate, as applied, and shall also bear the signature of the “R” Stamp holder that performed the replacement and the National Board Commissioned Inspector who authorized and witnessed the replacement.
5.3 NATIONAL BOARD INSPECTION FORMS
5.3.1 SCOPE
The following forms (5.3.2 through 5.3.7.1) may be used for documenting specific requirements as
indicated on the top of each form.
Note: Jurisdictions may have adopted other forms and may not accept these forms.
Page 45 of 92
CURRENT FORM NB-136 REPLACEMENT OF STAMPED DATA FORM
in accordance with provisions of the National Board Inspection Code Submitted to Submitted by
_____________________________________ _____________________________________ (name of jurisdiction) (name of owner)
_____________________________________ _____________________________________ (address) (address)
_____________________________________ _____________________________________
_____________________________________ _____________________________________ (telephone no.) (telephone no.)
1. Manufactured by _________________________________________________________________ (name and address)
2. Manufactured for _________________________________________________________________ (name and address)
3. Location of Installation ____________________________________________________________ (address) 4. Date Installed ___________________________________________________________________
5. Previously installed at _____________________________________________________________
6. Manufacturer’s Data Report Attached No Yes
7. Item registered with National Board No Yes, NB Number _____________________
8. Item identification Year built _________________
Type ____________________________________ Dimensions ________________
Mfg. Serial no. ____________________________ Jurisdiction no. _____________
MAWP _________________ psi Safety relief valve set at _________________psi
9. Complete the reverse side of this report with a true facsimile of the legible portion of the nameplate
10. If nameplate is lost or illegible, documentation shall be attached identifying the object to the Manufacturer’s Data Report referenced on this form.
11. I request authorization to replace the stamped data and/or nameplate on the above described pressure-retaining item in accordance with the rules of the National Board Inspection Code (NBIC).
Owner or User’s name
Signature _____________________________________________ Date ____________________
Title ___________________________________________________________________________ ______________________________________________________________________________
12. Authorization is granted to replace the stamped data or to replace the nameplate of the above described pressure-retaining item.
Signature _____________________________________________ Date ____________________ (chief inspector or authorized representative)
Jurisdiction _____________________________________________________________________
Page 46 of 92
The following is a true facsimile of the legible portion of the item’s nameplate. Please print. Where possible, also attach a rubbing of the nameplate.
(Back)
I certify that to the best of my knowledge and belief, the statements in this report are correct, and that the replacement information, data, and identification numbers are correct and in accordance with provisions of the National Board Inspection Code. Attached is a facsimile or rubbing of the stamping or nameplate. Name of Owner or User _______________________________________________________________
Signature _______________________________________________ Date ______________________ (Authorized representative)
Witnessed by ____________________________________________ Employer __________________ (Name of inspector)
Signature _________________________________ Date ________ NB Commission ____________ (Name of inspector)
Page 47 of 92
PROPOSED CHANGES TO FORM NB-136 REPLACEMENT OF STAMPED DATA FORM, NB-136
in accordance with provisions of the National Board Inspection Code Submitted to: Submitted by;
_____________________________________ _____________________________________ (name of jurisdiction) (name of owner, user, or certificate holder)
_____________________________________ _____________________________________ (address) (address)
_____________________________________ _____________________________________
_____________________________________ _____________________________________ (telephone no.) (telephone no.)
1. Manufactured by _________________________________________________________________ (name and address)
2. Manufactured for _________________________________________________________________ (name and address)
3. Location of Installation ____________________________________________________________ (address) 4. Date Installed ___________________________________________________________________
5. Previously installed at _____________________________________________________________
6. Manufacturer’s Data Report Attached No Yes
7. Item registered with National Board No Yes, NB Number _____________________
8. Item identification Year built _________________
Type ____________________________________ Dimensions ________________
Mfg. Serial no. ____________________________ Jurisdiction no. _____________
MAWP _________________ psi Safety relief valve set at _________________psi
9. Complete the reverse side of this report with a true facsimile of the legible portion of the nameplate or:
10. If nameplate is lost or illegible, traceability documentation, verified by the Inspector, shall be attached to this report. identifying the object. to the Manufacturer’s Data referenced on this form.
11. I request authorization to replace the stamped data and/or nameplate on the above described pressure-retaining item in accordance with the rules of the National Board Inspection Code (NBIC).
Owner or User’s Organization Name “R” Certificate Holder’s Name: Number ___________________
Signature _____________________________________________ Date ____________________
Title ___________________________________________________________________________ Verification of Traceability _________________ ________ NB Commission ____________ (Name of inspector)
12. Authorization is granted to replace the stamped data or to replace the nameplate of the above described pressure-retaining item.
Signature _____________________________________________ Date ____________________ (chief inspector or authorized representative)
Jurisdiction (if available) or NB Commission number ____________________________________
Page 48 of 92
The following is a true facsimile of the legible portion of the item’s original nameplate, (if available). Please print. Where possible, also attach a rubbing or picture of the nameplate. The following is a true facsimile of the item’s replacement stamping or nameplate
(Back)
I certify that to the best of my knowledge and belief, the statements in this report are correct, and that the replacement information, data, and identification numbers are correct and in accordance with provisions of the National Board Inspection code. Attached is a facsimile or rubbing of the stamping or nameplate. Name of Owner or User “R” Certificate Holder __________________________________________ Number
Signature _______________________________________________ Date ______________________ (Authorized representative)
Witnessed by ____________________________________________ Employer __________________ (Name of inspector)
Signature _________________________________ Date ________ NB Commission ____________ (Name of inspector)
ADDED
Page 49 of 92
PROPOSED FORM NB-136 REPLACEMENT OF STAMPED DATA FORM, NB-136
in accordance with provisions of the National Board Inspection Code Submitted to: Submitted by
_____________________________________ _____________________________________ (name of jurisdiction) (name of owner, user, or certificate holder)
_____________________________________ _____________________________________ (address) (address)
_____________________________________ _____________________________________
_____________________________________ _____________________________________ (telephone no.) (telephone no.)
1. Manufactured by _________________________________________________________________ (name and address)
2. Manufactured for _________________________________________________________________ (name and address)
3. Location of Installation ____________________________________________________________ (address) 4. Date Installed ___________________________________________________________________
5. Previously installed at _____________________________________________________________
6. Manufacturer’s Data Report Attached No Yes
7. Item registered with National Board No Yes, NB Number _____________________
8. Item identification Year built _________________
Type ____________________________________ Dimensions ________________
Mfg. Serial no. ____________________________ Jurisdiction no. _____________
MAWP _________________ psi Safety relief valve set at _________________psi
9. Complete the reverse side of this report with a true facsimile of the legible portion of the nameplate or:
10. If nameplate is lost or illegible, traceability documentation, verified by the Inspector, shall be attached to this report.
11. I request authorization to replace the stamped data and/or nameplate on the above described pressure-retaining item in accordance with the rules of the National Board Inspection Code (NBIC).
“R” Certificate Holder: Number _________________
Signature _____________________________________________ Date ____________________
Title ___________________________________________________________________________ Verification of Traceability _________________ ________ NB Commission ____________ (Name of inspector)
12. Authorization is granted to replace the stamped data or to replace the nameplate of the above described pressure-retaining item.
Signature _____________________________________________ Date ____________________ (chief inspector or authorized representative)
Jurisdiction (if available) or NB Commission number ____________________________________
Page 50 of 92
The following is a true facsimile of the legible portion of the item’s original nameplate, (if available). Please print. Where possible, also attach a rubbing or picture of the nameplate. The following is a true facsimile of the item’s replacement stamping or nameplate
(Back)
I certify that to the best of my knowledge and belief, the statements in this report are correct, and that the replacement information, data, and identification numbers are correct and in accordance with provisions of the National Board Inspection code. “R” Certificate Holder ______________________________ Number
Signature _______________________________________________ Date ______________________ (Authorized representative)
Witnessed by ____________________________________________ Employer __________________ (Name of Inspector)
Signature _________________________________ Date ________ NB Commission ____________ (Name of Inspector)
Page 51 of 92
NBIC Part 2 2.3.6.8 INSPECTION OF LIQUID CARBON DIOXIDE STORAGE VESSELS
A) This section provides requirements for the inspection of Liquid Carbon Dioxide Storage Vessels (LCDSV’s), fill boxes, fill lines and pressure relief discharge/vent circuits used for carbonated beverage systems, swimming pool PH control systems and other fill in place systems of liquid CO2.
B) General Requirements (enclosed and unenclosed areas)
The Inspector shall verify that:
a. LCDSV’s are not located within 10 feet (3050 mm) of elevators, unprotected platform ledges or other areas where falling would result in dropping distances exceeding half the container height.
b. LCDSV’s are installed with sufficient clearance for filling, operation, maintenance, inspection and replacement.
c. LCDSV’s are not installed on roofs. d. LCDSV’s are safely supported. e. LCDSV’s are not located within 36 in. (915 mm) of electrical service panels. f. LCDSV’s located outdoors in areas in the vicinity of vehicular traffic are
guarded to prevent accidental impact by vehicles.
C) Enclosed area LCDSV Installations The Inspector shall verify that:
1) Permanent LCDSV installations with remote fill connections: a. Are equipped with a gas detection system installed in accordance with NBIC Part 2 XX; b. Have signage posted in accordance with NBIC Part 12 XX c. Are equipped with fill boxes; fill lines and pressure relief/vent valve circuits installed in accordance with NBIC Part 2 XX 2) Portable LCDSV installations with no permanent remote fill connection:
Warning: LCDSV’s shall not be filled indoors or in enclosed areas under any circumstances. Tanks must always be moved to the outside to an unenclosed, free airflow area for filling. a. Are equipped with a gas detection system installed in accordance with NBIC Part 2 XX; b. Have signage posted in accordance with NBIC Part 2 XX; c. Have a pressure relief/vent valve circuit connected at all times except when the tank is being removed for filling. Connections may be fitted with a quick disconnect fitting meeting the requirements of NBIC Part 2 XX; d. Are provided with a pathway that provides a smooth rolling surface to the outdoor, unenclosed fill area. There shall not be any stairs or other than minimal inclines in the pathway.
Page 52 of 92
D) FILL BOX LOCATION / PRESSURE RELIEF/VENT VALVE CIRCUIT TERMINATION The Inspector shall verify that fill boxes and/or pressure relief/vent valve terminations are above grade outdoors in an unenclosed, free airflow area and that the fill connection is located so not to impede means of egress or the operation of sidewalk cellar entrance doors, including during the delivery process and that they are:
a) At least three (3) feet (915 mm) from any door or operable windows.*
b) At least three (3) feet (915 mm) above grade.*
c) Not located within ten (10) feet (3050 mm) from any air intakes measured from side to side at the same level or below.*
d) Not located within ten (10) feet (3050 mm) of below grade stair wells.* * Note: Many systems installed prior to 1/1/2014 do not meet the above requirements and the local Jurisdiction should be consulted for guidance.
E) GAS DETECTION SYSTEMS Rooms or areas where carbon dioxide storage vessel(s) are located indoors or in enclosed or below grade outdoor locations shall be provided with a gas detection and alarm system for general area monitoring that is capable of detecting and notifying building occupants of a CO2 gas release. Gas detection systems shall be installed and tested in accordance with manufactures installation instructions and the following requirements:
a) The Inspector shall verify that the gas detection system and audible alarm is operational and tested in accordance with manufacturer’s guidelines.
b) The Inspector shall verify that audible alarms are placed at the entrance(s) to the room or area where the carbon dioxide storage vessel and/ or fill box is located to alert anyone who might try to enter the area of a potential problem.
F) SIGNAGE
The Inspector shall verify that warning signs are posted at the entrance to the building, room, enclosure, or enclosed area where the container is located. The warning sign shall be at least 8 in (200mm) wide and 6 in. (150mm) high. The wording shall be concise and easy to read. The upper portion of the sign must be orange as shown in figure NBIC Part 2 XX. When no jurisdictional requirements exist, the minimum letter height shall be in accordance with NEMA, American National Standard for Environmental and Facility Safety Signs (ANSI Z535.2). The warning signs shall state the following:
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Figure XX
a) Additional instructional signage shall be posted outside of the area where the container
is located and such signage shall contain at minimum the following information: Carbon Dioxide Monitors for general area monitoring (not employee personal exposure monitoring) are provided in this area. These monitors are set to alarm at 5,000 ppm (1.5% concentration by volume) for the low level alarm and at 30,000 ppm (3% concentration by volume) for high level alarm.
Low Level Alarm (5,000 ppm) – Provide appropriate cross ventilation to the area. Personnel may enter area for short periods of time (not to exceed 15 minutes at a time) in order to identify and repair potential leaks.
High Level Alarm (30,000 ppm) – Personnel should evacuate the area and nobody should enter the affected area without approved self-contained breathing apparatus until the area is adequately ventilated and the concentration of CO2 is reduced below the high alarm limit.
G) VALVES, PIPING, TUBING AND FITTINGS
1) Materials – The Inspector shall verify that the materials selected for valves, piping,
tubing, hoses and fittings used in the LCDSV system meet the following requirements:
a. Components shall be rated for the operational temperatures and pressures encountered in the applicable circuit of the system
b. All valves and fittings used on the LCDSV shall be rated for the maximum allowable working pressure stamped on the tank.
c. All piping, hoses and tubing used in the LCDSV system shall be rated for the working pressure of the applicable circuit in the system and have a burst pressure rating of at least four times the maximum allowable working pressure of the piping, hose or tubing.
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2) Isolation Valves - Each LCDSV shall have an isolation valve installed on the fill line
and tank discharge, or gas supply line in accordance with the following requirements: a. Isolation valves shall be located on the tank or at an accessible point as near
to the storage tank as possible. b. All valves shall be designed or marked to indicate clearly whether it is open or
closed. c. All valves shall be capable of being locked or tagged in the closed position for
servicing. d. Gas Supply and Liquid CO2 Fill Valves shall be clearly marked for easy
identification.
3) Pressure Relief Valves- Each LCDSV shall have at least one ASME/NB stamped & certified pressure relief valve with a pressure setting at or below the MAWP of the tank. The minimum pressure relief valve capacity shall be designated by the manufacture. Additional relief valves that do not require ASME stamps may be added as per the Compressed Gas Association. Discharge lines from the pressure relief valves shall be sized in accordance tables NBIC Part 2 xx and XX.
4) Pressure Relief/Vent Line- The Inspector, where possible, shall verify the integrity
of the pressure relief/vent line from the vessel pressure relief valve to outside vent line discharge fitting. All connections shall be securely fastened to the LCDSV. The minimum size and length of the line shall be in accordance with table NBIC Part 2, XX and XX. Fittings or other connections that may result in a localized reduction in diameter have been factored into the lengths given by the tables NBIC Part 2, XX and XX.
Note: Due to the design of the LCDSV the discharge line may be smaller in diameter than the pressure relief valve outlet size but shall not be smaller than that shown in tables NBIC Part 2, XX and XX.
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Table XX Minimum LCDSV System Pressure Relief/Vent Line Requirements (Plastic/Polymer)
Tank Size (Pounds)
Fire Flow Rate Requirements (Pounds per Minute)
Maximum Length of 3/8 inch ID Plastic/Polymer Materials Tube Allowed
Maximum Length of ½ inch ID Plastic/Polymer Materials Tube Allowed
Less than 500 2.60 maximum 100 feet 100 feet 500-750 3.85 maximum 100 feet 100 feet Over 750-1000 5.51 maximum N/A see ½ inch 100 feet
Table XX a) Metric Minimum LCDSV System Pressure Relief /Vent Line Requirements (Metallic)
Tank Size (Kg)
Fire Flow Rate Requirements (Kg per Minute)
Maximum Length of 10mm ID Nominal Metallic Tube Allowed
Maximum Length of 13mm ID Nominal Metallic Tube Allowed
Less than 227 1.18 maximum 24 m 30.5 m 227-340 1.75 maximum 17 m 30.5 m Over 340-454 2.50 maximum 5.5 m 30.5 m
Table XX b) Metric Minimum LCDSV System Pressure Relief/Vent Line Requirements (Plastic/Polymer)
Tank Size (kg)
Fire Flow Rate Requirements (kg per Minute)
Maximum Length of 10 mm ID Nominal Metallic Tube Allowed
Maximum Length of 13 mm ID Plastic/Polymer Materials Tube Allowed
Less than 227 1.18 maximum 30.5 m 30.5 m 227-340 1.75 maximum 30.5 m 30.5 m Over 340-454 2.5 maximum N/A see 13 mm 30.5 m Note: Due to the design of the LCDSV the discharge line may be smaller in diameter than the pressure relief valve outlet size but shall not be smaller than that shown in tables NBIC Part 2, XX and XX.
Tank Size (Pounds)
Fire Flow Rate Requirements (Pounds per Minute)
Maximum Length of 3/8 inch ID Nominal Metallic Tube Allowed
Maximum Length of ½ inch ID Nominal Metallic Tube Allowed
Less than 500 2.60 maximum 80 feet 100 feet 500-750 3.85 maximum 55 feet 100 feet Over 750-1000 5.51 maximum 18 feet 100 feet
Table XX Minimum LCDSV System Pressure Relief /Vent Line Requirements (Metallic)
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Subject: Part 2, Supplement 2, S2.8.1 SAFETY VALVES File Number: NB13-0901 Proposal: Add language to address the safety valve discharge piping. Explanation: Add new items 8-12 Add the following:
8) The safety valve(s) shall be connected so as to stand in an upright position with the spindle vertical.
9) The discharge from the safety valve(s) shall be arranged that there is no danger of scalding either the operator(s) or individuals who may be in the vicinity of the boiler. If the valve(s) is a top discharge design, no discharge piping is required. If a side discharge design valve(s) is used, an elbow should be attached to the outlet to assure a vertical discharge. The elbow must be located as close to the valve(s) as possible to minimize reaction moment stress.
10) Provision for ample gravity drain shall be made in the discharge pipe at or near each safety valve, and where water can collect.
11) If the boiler is equipped with a canopy, the elbow may be other than 90 degrees to direct the discharge out from under the canopy, while still directing the discharge to a safe location. The elbow must be located as close to the valve(s) as possible to minimize reaction moment stress.
12) If the boiler is equipped with a canopy, the discharge may be piped through the canopy. When the discharge piping is piped through a canopy, the elbow must be located as close to the valve as possible to minimize reaction moment stress. The discharge piping may be a larger pipe than the discharge size of the valve. Discharge piping shall be completely supported separate from the valve and elbow so no extra loading is transmitted to the safety valve(s).
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IN 14‐0101 rev 1, 1‐15‐14
Committee Question:
When temperature limits are not required to be placed on the original manufacturer’s nameplate in
accordance with the original code of construction, may the temperature field for Figures 5. 7. 5 b) and
5.7.5 c) be indicated as N/A?
Committee’s Reply: Yes
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PROPOSED INTERPRETATION
Inquiry No.
IN14-0201
Source
Marshall Mlachak
Subject Part 3, 1.8.5 q) Edition
2013 Edition
Question
Question: If audit personnel are qualified in accordance with the requirements of ANS/ASME N45.2.23, Qualification of Quality Assurance Program Audit Personnel for Nuclear Power Plants may they perform the audits specified in 1.8.5 q)?
Reply
Yes. NQA-1 is based upon ANSI/ASME N45.2-1977and the seven daughter standards of N45.2 including ANSI N45.2.23, Qualification of Quality Assurance Program Audit Personnel for Nuclear Power Plants. The qualification requirements are equivalent.
Committee’s Question
Committee’s Reply
Rationale
SC Vote
Unanimous No. Affirmative No. Negative No. Abstain No. Not Voting
NBIC Vote
Unanimous No. Affirmative No. Negative No. Abstain No. Not Voting
Negative Vote Comments
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IN14‐0501
Code Interpretation
Inquiry: Does the NBIC Part 3 in Section 3.3.4.3 d) require tubes below “t min” to be repaired?
Reply: No. The NBIC Part 3 does not provide rules for determining when a repair must be performed.
Background Information: In this particular case, a boiler tube failed due to OD corrosion in a division
wall near the crouch area. Upon review, it was found that several tubes exhibited corrosion due to
waterwall washing and migration of the water through the insulation to the tube surface over the
course of 60 years of operation. Several wall thickness readings were taken in areas where this
corrosion was visually detected and several areas were found below “t min”. Many areas were weld
repaired restoring wall thickness in these corrosion areas to at least 80% of “t min”.
The boiler OEM previously issued a bulletin which allowed the owner‐operators to operate boilers with
tube wall thicknesses down to 70% of “t min” if certain conditions are met in the bulletin. These are
presented in the OEM bulletin (attached) and all conditions have been met in this bulletin. The owner
presented this information to the Commissioned Inspector (CI) for all tubes that were less than “t min”
but greater than 80% and the CI referred to the Jurisdictional authority.
The jurisdiction interprets this section as,
The owner‐user believes the intent of this section includes conditions where wall thicknesses are less
than t‐min. This is further confirmed by the last sentence in this section, “This may be necessary when
considering such items as size limitations of repaired areas, minimum tube thickness to be repaired, tube
environment, location of tube in the boiler, and other similar conditions”. The owner believes “minimum
tube thickness” applies to conditions where actual wall thickness is less than “t min” and continued
operation of this boiler where tube thicknesses meets 80% t min and is based on reasonable analyses
meets the intent of this section of the code. See interpretation 98‐05
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5) The term t, as used above to determine SB, HB and GCB shall be the nominal thickness of either a full penetrationweld,orthegroovewelddepthofapartialpenetrationrepairweld.Ifafilletweldisusedin combination with a groove weld, the nominal thickness for PWHT shall be the depth of the groove weld.
2.5.3 alternative Welding metHods WitHout PostWeld Heat treatment
a) Under certain conditions, postweld heat treatment, in accordance with the original code of construction, may be inadvisable or impractical. In such instances, the following alternative methods may be used.
b) Competent technical advice shall be obtained from the manufacturer of the pressure-retaining item or from anotherqualifiedsource,suchadvicebeingespeciallynecessaryifthealternativeistobeusedinhighlystressed areas, if service conditions are conducive to stress corrosion cracking, if materials are subject to hydrogen embrittlement, or are operating at temperatures in the creep range, or if the alternative is being considered for “on-stream” repairs or “hot tapping” on piping systems. Selection of the welding method used shall be based on the rules of the original code of construction together with the above mentioned advice concerning the adequacy of the weld in the as-welded condition at operating and pressure test conditions.
c) When reference is made in this Section to materials by the ASME designation, P-Number and Group Num-ber, the requirements of this Section apply to the applicable materials of the original code of construction, either ASME or other, which conform by chemical composition and mechanical properties to the ASME P-Number and Group Number designations.
d) The detailed welding methods listed in the following subsections may be used as an alternative to post-weld heat treatment (PWHT). NBIC Part 3, 2.5.3.1 is a method in which the welding procedure requires an elevation of the preheat temperature. In contrast, NBIC Part 3, 2.5.3.2 thru 2.5.3.5, are methods in which the welding procedure requires the use of a temper-bead welding technique. In 2.5.3.5 is a method in which the welding procedure used for joining dissimilar materials requires either an elevation of the preheat temperature or a temper-bead welding technique, depending on the chemical composition of the basemetalthatisjoinedtoanausteniticsteel.Temper-beadweldingprocedurenomenclatureisdefinedin Section IX of the ASME Boiler and Pressure Vessel Code. Typically, this technique minimizes heat input of the initial beads, thus limiting heat beyond the weld heat-affected zone (HAZ) of the base metal. Heat input shall be increased for successive beads in accordance with the rules of QW-290 for temper beadweldinginASMESectionIX.TheWeldingProcedureandWelderPerformanceQualificationsshall,in all cases, be in accordance with the requirements of the latest Edition of Section IX of the ASME Boiler and Pressure Vessel Code.
e) Nondestructive Examination of Welds
Prior to welding, the area prepared for welding shall be examined using either the Magnetic Particle (MT) ortheLiquidPenetrant(PT)examinationmethodtodeterminethatnodefectsexist.Afterthefinishedweldhas reached ambient temperature, the weld shall be examined again by either of the above methods to determine that no defects exist using acceptance standards acceptable to the Inspector or original code of construction. In addition, welds greater than 3/8 in. (9.6 mm) deep or welds in a boiler, pressure vessel, or piping system that were originally required to be radiographed by the rules of the original code of con-struction, shall be radiographically examined. In situations where it is not practical to perform radiography, the accessible surfaces of each non radiographed repair weld shall be fully examined using the MT or PT method to determine that no defects exist and the maximum allowable working pressure and/or allowable temperature shall be re-evaluated to the satisfaction of the jurisdiction at the location of installation.
f) Methods that may be used as alternatives to postweld heat treatment are described in the following sub-sections.
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2.5.3.1 Welding metHod 1
Whenusingthismethod,thefollowingisrequired:
a) This method may be used when the applicable rules of the original code of construction did not require notch toughness testing;
b) The materials shall be limited to P-No. 1, Groups 1, 2, and 3 and to P-No. 3, Groups 1 and 2 (excluding Mn-Mo steels in Group 2), as permitted for welded construction by the applicable rules of the original code of construction;
c) The welding shall be limited to the Shielded Metal-Arc welding (SMAW), Gas Metal-Arc Welding (GMAW), Fluxcored Arc Welding (FCAW), and Gas Tungsten-Arc Welding (GTAW) processes;
d) TheWeldersandWeldingOperators,WeldingProceduresSpecificationsshallbequalifiedinaccordancewith the applicable rules of the original code of construction, except that no postweld heat treatment shall be applied to the test coupon;
e) Theweldareashallbepreheatedandmaintainedataminimumtemperatureof300˚F(149˚C)during welding.Alternatively,forP-No.1,Groups1,2and3materials,thepreheatmaybereducedto175˚F
(79˚C)provided:1) Provided the carbon equivalent of the base material to be welded is determined to be 0.40 or less.
2) Theelectrodesandfillermetalsareclassifiedbythefillermetalspecificationwithadiffusible–hydrogen designator of H4 or lower.
3) Whenshieldinggasisused,itshallhaveadewpointthatis-60˚F(-50˚C)orlower.
f) The preheat temperature shall be checked to assure that 4 in. (102 mm) of the material or four times the material thickness (whichever is greater) on each side of the groove (or full thickness of joint for a groove weld) is maintained at the preheat temperature during welding. When the weld does not penetrate through the full thickness of the material, the preheat need only be maintained at a distance of 4 in. (102 mm) or four times the depth of the repair weld, whichever is greater, on each side of the joint.
2.5.3.2 Welding metHod 2
Whenusingthismethod,thefollowingisrequired:
a) This method shall be used when the applicable rules of the original code of construction required notch toughness testing or shall be used when the applicable rules of the original code of construction did not require notch toughness testing provided the adequacy of the notch toughness of the weld, including the heat-affectedzone,intheas-weldedconditionatoperatingandpressuretestconditionsisverified;
b) The materials shall be limited to carbon and low alloy steels permitted for welded construction by the applicable rules of the original code of construction, including those materials conforming to any of the following ASME P-No.designations:P-No.1,Groups1,2,and3;P-No.3,Groups1,2,and3;P-No.4;P-No.5A;P-No.9A;P-No. 10A; P-No. 10B; P-No. 10C; P-No. 11A; or P-No. 11B;
c) The welding shall be limited to the Shielded Metal-Arc Welding (SMAW), Gas Metal-Arc Welding (GMAW), Fluxcored-Arc Welding (FCAW), and Gas Tungsten-Arc Welding (GTAW) processes.
d) TheWeldingProceduresSpecificationsshallbequalifiedinaccordancewiththetemperbeadprocedurequalificationrequirementsinQW-290ofASMESectionIX,andshallincludethefollowingadditionalre-quirements:
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1) For P-No. 1 Groups 1, 2, and 3 and P-No. 3 Groups 1, 2, and 3, the minimum preheat temperature shall be 350°F (177°C), and the maximum interpass shall be 450°F (232°C).
2) For P-No. 9A, P-No. 10A, P-No. 10B, P-No. 10C, P-No. 11A, or P-No. 11B, the minimum preheat and interpass temperature requirements shall be in accordance with the guidelines in NBIC Part 3, 2.5.1.
3) For P-No. 4 and P-No. 5A materials, the minimum preheat, interpass temperature, and technique shall be in accordance with NBIC Part 3, 2.5.3.4. The repair depth for temper bead repairs to pres-sure retaining items of P-No. 4 and P-No. 5A materials is limited to welds not penetrating through full thickness.
4) For ASME Section VIII, Division 2 pressure vessels, where application of PWHT on in-service ves-sels has been demonstrated to cause harm to vessel material, full thickness temper bead repairs are permitted to pressure-retaining items of P-No. 4 and P-No. 5A materials. They shall be completed per NBIC,Part3,3.3.5withthefollowingrequirements:
a)Thefullthicknessrepairweldshallbeverifiedasbeingthefullpenetration. b) Volumetric examination of the full thickness weld shall be performed.
e) Thetestmaterialfortheweldingprocedurequalificationshallbeofthesamematerialspecification(in-cludingspecificationtype,grade,class,andconditionofheattreatment)asthematerialbeingrepaired.In the event that the notch toughness of the material to be repaired is unknown, evidence from tests of that material or from another acceptable source (see NBIC Part 3, 2.5.3) may be used for the base metal notch toughness when qualifying the WPS as required in NBIC Part 3, 2.5.3.2(h). In the event that the originalmaterialspecificationisobsolete,thetestmaterialusedshouldconformascloselyaspossibleto the original material used for construction based on nominal composition and carbon equivalent (IIW Formula),7 but in no case shall the material be lower in strength.
f) ThequalificationthicknessforthetestplatesandrepairgroovedepthsshallbeinaccordancewithASMESection IX;
g) Theorganizationmakingtherepairshallinclude,whenqualifyingitsWPS,sufficientteststodeterminethat the notch toughness of the weld metal and the heat-affected zone of the base metal in the “as-welded” condition is adequate at the minimum operating and pressure test temperatures (including start-up and shutdown). If for reasons of corrosion resistance, special hardness limits are necessary, such limits shall be included when qualifying the WPS;
h) Notch toughness shall be determined and evaluated by Charpy impact tests in accordance with the provi-sions of the original code of construction at the temperature determined in accordance with NBIC Part 3, 2.5.3.2(d). Exemptions from impact testing described in the original code of construction are not applicable;
i) FortheweldingprocessinNBICPart3,2.5.3.2(c),useofausteniticorferriticfillermetalsispermitted.Forferriticfillermetals,useonlyelectrodesandfillermetalsthatareclassifiedbythefillermetalspecificationwith a diffusible-hydrogen designator of H8 or lower. When shielding gases are used with a process, the gas shall exhibit a dew point that is below -60°F (-50°C). Surfaces on which welding will be done shall be maintained in a dry condition during welding and be free of rust, mill scale, and hydrogen producing contaminants such as oil, grease, and other organic materials;
j) Aftertheweldhasbeendepositedflushwiththebasemetal,asurfacetemperreinforcingweldlayershallbe applied;
7 The IIW Carbon Equivalent Formula is CE= C+ Mn/6 + (Cr+Mo+V)/5 + (Ni+Cu)/15. Elements are expressed in Weight Percent Amounts.
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k) For welds made by SMAW and FCAW, after completion of welding and without allowing the weldment to cool below the minimum preheat temperature, the temperature of the weldment shall be raised to a temperature of 450°F (232°C) minimum for a minimum period of two hours. This hydrogen bake-out treatmentmaybeomittedprovidedtheelectrodeusedisclassifiedbythefillermetalmanufacturerwithadiffusible-hydrogen designator of H4 (e.g., E7018-H4);
l) Afterthefinishedrepairweldhascooledtoambienttemperature,thesurfacetemperreinforcinglayershallberemovedsubstantiallyflushwiththesurfaceofthebasematerial.
2.5.3.3 Welding metHod 3
Whenusingthismethod,thefollowingisrequired:
a) This method may be used when the applicable rules of the original code of construction did not require notch toughness testing;
b) The materials shall be limited to any P-No. 1 or P-No. 3 material as permitted for welded construction by the applicable rules of the original code of construction;
c) The welding shall be limited to the SMAW, FCAW, and GTAW processes;
d) ThetestmaterialfortheweldingprocedurequalificationshallbeofthesameP-No.andGroupNo.asthebasematerialspecificationoftherepair.Intheeventthattheoriginalmaterialspecificationisobsolete,the test material used should conform to the nominal composition and carbon equivalent (IIW Formula)8 as the material being repaired, but in no case shall the material be lower in strength;
e) If for reasons of corrosion resistance, special hardness limits are necessary, such limits shall be included when qualifying the WPS;
f) ThequalificationthicknessforthetestplatesandrepairgroovedepthsshallbeinaccordancewithASMESection IX;
g) TheWPSshallbequalifiedinaccordancewiththetemperbeadprocedurequalificationrequirementsinQW-290ofASMESectionIX,andshallincludethefollowingadditionalrequirements:
1) The minimum preheat temperature for welding shall be 350°F (177° C) and the maximum interpass
temperature shall be 450°F (232°C);
2) FortheweldingprocessesinNBICPart3,2.5.3.3c),useofausteniticorferriticfillermetalispermit-ted.Forferriticfillermetals,useonlyelectrodesorfillermetalsthatareclassifiedbythefillermetalspecificationwithadiffusible-hydrogendesignatorofH8orlowermaybeused.Whenshieldinggasesare used with a process, the gas shall exhibit a dew point that is below -60°F (-50°C). Surfaces on which welding will be done shall be maintained in a dry condition during welding and be free of rust, mill scale, and hydrogen producing contaminants such as oil, grease, and other organic materials;
3) After completion of welding using SMAW and without allowing the weldment to cool below the mini-mum preheat temperature, the temperature of the weldment shall be raised to a temperature of 450°F (232°C) minimum for a minimum period of two hours. This hydrogen bake-out treatment may be omit-ted,providedtheelectrodeusedisclassifiedbythefillermetalmanufacturerwithadiffusible-hydrogendesignator of H4 (e.g., E7018-H4);
8 The IIW Carbon Equivalent Formula is CE= C+ Mn/6 + (Cr+Mo+V)/5 + (Ni+Cu)/15. Elements are expressed in Weight Percent Amounts.
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4) Afterthefinishedrepairweldhascooledtoambienttemperature,thefinaltemperbeadreinforcementlayershallberemovedsubstantiallyflushwiththesurfaceofthebasematerial.
2.5.3.4 Welding metHod 4
Whenusingthismethod,thefollowingisrequired:
a) This method is limited to repair welds in pressure retaining items for which the applicable rules of the original code of construction did not require notch toughness testing. The repair depth for temper bead repairs to pressure retaining items is limited to welds not penetrating though the full thickness.
For ASME Section VIII Division 2 pressure vessels, where application of PWHT on in-service vessels has been demonstrated to cause harm to vessel material, full thickness temper bead repairs are permitted. TheyshallbecompletedperNBICPart3,3.3.5withthefollowingrequirements:
1) Thefullthicknessrepairweldshallbeverifiedasbeingfullpenetration.
2) Volumetric examination of the full thickness weld shall be performed.
b) The materials shall be limited to P-No. 4, Groups 1 and 2, and P-No. 5A steels as permitted for welded construction by the applicable rules of the original code of construction;
c) The welding shall be limited to the SMAW, FCAW, GMAW or GTAW processes using low-hydrogen elec-trodesandfillermetalsclassifiedbythefillermetalspecificationwithadiffusible-hydrogendesignatorof H8 or lower, and suitably controlled by maintenance procedures to avoid contamination by hydrogen producing sources. The surface of the metal prepared for welding shall be free of contaminants;
d) ThetestmaterialfortheweldingprocedurequalificationshallbeofthesameP-No.andGroupNo.astheoriginalmaterialspecificationfortherepair.Intheeventthattheoriginalmaterialspecificationisobsolete,the test material used shall conform to the nominal composition and carbon equivalent (IIW formula)9 as the original material used for construction, and in no case shall the material be lower in strength;
e) If for reasons of corrosion resistance, special hardness limits are necessary, such limits shall be included when qualifying the WPS;
f) ThequalificationthicknessforthetestplatesandrepairgroovedepthsshallbeinaccordancewithASMESection IX;
g) Theweldingprocedures(WPS)shallbequalifiedinaccordancewiththetemperbeadprocedurequalifica-tionrequirementsinQW-290ofASMESectionIX,andshallincludethefollowingadditionalrequirements:
1) The minimum preheat temperature for welding shall be 300°F (150°C) for P-No. 4 material and 400°F (200°C) for P-No. 5A material. The preheat temperature shall be checked to ensure that 4 in. (102mm) of the material or four times the material thickness (whichever is greater) on each side of the groove (or full thickness of joint for a groove weld) is maintained at the minimum temperature during weld-ing. The interpass temperature shall not exceed 800°F (430°C). When the weld does not penetrate through the full thickness of the material, the minimum preheat and maximum interpass temperature need only be maintained for 4 in. (102mm) or four times the depth of the repair weld (whichever is greater) on each side of the joint;
9 The IIW Carbon Equivalent Formula is CE=C+ Mn/6 + (Cr+Mo+V)/5 + (Ni+Cu)/15. Elements are expressed in Weight Percent Amounts
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2) FortheweldingprocessesinNBICPart3,2.5.3.4c),useofaustenticorferriticfillermetalispermit-ted.Forferriticfillermetals,useonlyelectrodesorfillermetalsthatareclassifiedbythefillermetalspecificationwithadiffusible-hydrogendesignatorofH8orlower.Whenshieldinggasesareusedwitha process, the gas shall exhibit a dew point that is below -60°F (-50°C). Surfaces on which welding will be done shall be maintained in a dry condition during welding and be free of rust, mill scale, and hydrogen producing contaminants, such as oil, grease, and other organic materials;
3) Aftertheweldhasbeendepositedflushwiththebasemetal,asurfacetemperreinforcingweldlayershall be applied.;
4) For welds made by the SMAW and FCAW processes, after completion of welding and without allowing the weldment to cool below the minimum preheat temperature, the temperature of the weldment shall be raised to 450°F (232°C) minimum for a minimum period of two hours. This hydrogen bake-out treat-mentmaybeomitted,providedtheelectrodeusedisclassifiedbythefillermetalmanufacturerwithadiffusible-hydrogen designator of H4 (e.g., E7018 H4);
5) Afterthefinishedrepairweldhascooledtoambienttemperature,thesurfacetemperreinforcingweldlayershallberemovedsubstantiallyflushwiththesurfaceofthebasemetal(andforafilletweldtothe required size and suitable contour of the toes).
2.5.3.5 Welding metHod 5
Whenusingthismethod,thefollowingisrequired:
a) This welding method may be used when the applicable rules of the original code of construction or the construction standard or code selected permit joining dissimilar materials used in pressure-retaining items;
b) The materials shall be limited to ASME P-No. 1, Groups 1, 2, and 3, P-No. 3, Groups 1, 2, and 3, P-No. 4, P-No. 5A, P-No. 9A, P-No. 10A, P-No. 10B, P-No. 10C, P-No. 11A, P-No. 11B joined to either P-No. 8, P-No. 42, P-No. 43, or P-No. 45, as permitted for welded construction by the applicable rules of the original code of construction;
c) The welding shall be limited to the SMAW, FCAW, GMAW and machine or automatic GTAW processes. ThefillermetalusedforjoiningthedissimilarmaterialsshallbeeitherA-No8orNickel-Chromealloyclas-sification(F-No43).Whenselectingafillermetalfordissimilarmetalweldjoints,determineiftheweldjointwillbeexposedtoelevatedtemperatureservice.A-No8fillermetalsexposedtoservicetemperaturesgreater than 800°F (427°C) will exhibit reduced creep life along the fusion zone of the ferritic material due tocarbondiffusion.Instead,alowhydrogen,Nickel-Chromiumalloyclassificationfillermetalshallbeusedfor dissimilar weld joints exposed to service temperatures at or above 800°F (427°C);
d) TheWPSshallbequalifiedinaccordancewiththetemperbeadrulesofQW-290inASMESectionIX;.
e) Iftheoriginalcodeofconstructiondidnotrequirenotchtoughnesstesting,qualificationofweldingproce-dures (WPS) for joining ASME P-No. 1, P-No. 3 ferritic materials to either P-No. 8, P-No. 42, P-No. 43, or P-No. 45 materials shall be in accordance with requirements in either NBIC Part 3, 2.5.3.1, Welding Method 1 or in NBIC Part 3, 2.5.3.3, Welding Method 3.
f) Iftheoriginalcodeofconstructiondidnotrequirenotchtoughnesstesting,qualificationofweldingproce-dures (WPS) for joining ASME P-No. 4, P-No. 5A ferritic materials to either P-No. 8, P-No. 42, P-No. 43, P-No. 45 materials shall be in accordance with the requirements in NBIC Part 3, 2.5.3.4, Welding Method 4;
For NBIC Committee use only
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Action Item NB13‐503 – NAMEPLATE ATTACHMENT REV.3 ‐ Miletti
g) The subject nameplate shall be securely attached using a method compatible with the structure or stand-off
bracket supporting the nameplate, in a manner that will impede easy removal. The method of attaching this
nameplate, as permitted by the original Code of construction, may include, but is not limited to:
- Welding
- Adhesive, bonding or cementing
- Tamper-resistant mechanical fasteners of suitable metal construction
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NBIC – ASME Liaison Report(i.e. What’s Happening at ASME Conformity Assessment?
Separation of Conformity Assessment Requirements CA-1 Standard published; to be referenced by Book sections
BPV Parts Fabrication Certificate Program New “Part” Designator for Fabricators w/o design responsibility
Certificates to apply across Codes Sections
Single Certification Mark
ANDE Personnel Certification Program 3rd party central certification for NDE personnel
Alternative to Book Section requirements
Transportable personnel credentials
QAI initiatives to improve feedback on AIA performance Team Leader reports during survey reviews
Desk Top reviews
Certificate Numbers on Data Plates
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NB-240, Rev. 12 Page 1 of 24
National Board Inspection Code Procedure
Approved by NBIC Committee: January 23, 2013 Approved by the Board of Trustees: Approved by ANSI:
The National Board of Boiler & Pressure Vessel Inspectors
1055 Crupper Avenue Columbus, OH 43229-1183
Phone: (614)888-8320
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Table of Contents Page 1.0 Purpose 3 2.0 Responsibilities 3 3.0 Definitions 3 4.0 Committee Structure 4 5.0 Duties of NBIC Committee, Subcommittee, Subgroup and Task Group Membership 12 6.0 Meetings 13 7.0 Voting 15 8.0 National Board Inspection Code Publication Administration 17 9.0 Due Process 22 10.0 Records 24
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1.0 Purpose
This procedure defines the organization, scope, duties and responsibilities of the NBIC Committee, subcommittees, subgroups and task groups. The NBIC Committee is established by the Board of Trustees for the purpose of maintaining the NBIC. The NBIC Committee is accredited by ANSI as a “developer of American National Standards” in accordance with the ANSI Essential Requirements. This procedure also describes the administrative process for the publication of the National Board Inspection Code. Revisions to this procedure must be approved by the NBIC Committee, the Board and ANSI. A copy of this procedure or any referenced document is either available on the National Board’s Web site: www.nationalboard.org or may be obtained from the NBIC secretary.
2.0 Responsibilities
The Executive Director of the National Board is responsible for ensuring that the requirements of this procedure are met. The Secretary of the NBIC Committee is responsible for the day-to-day implementation of this procedure. Other responsibilities are described throughout this procedure.
3.0 Definitions
The following are terms and their definitions used throughout this document. ANSI American National Standards Institute Board The Board of Trustees of the National Board Code The National Board Inspection Code (NBIC) NBIC Committee The NBIC Main Committee, accredited by ANSI as the
final consensus body for the purpose of approving American National Standards
committee The NBIC Committee and all subcommittees, subgro ups and task groups National Board The National Board of Boiler and Pressure Vessel
Inspectors
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NB Mark A National Board Code Symbol Stamp NBIC The National Board Inspection Code which was
established to provide rules and guidelines for the repair, alteration, inspection, installation, maintenance and testing of boilers, pressure vessels and other pressure retaining items.
subcommittee A unit established to address recurring functions, address specific issues or maintain specific sections of the NBIC. A subcommittee is established by the NBIC Committee. Each subcommittee will follow rules for consensus approval insofar as possible but is not considered the final consensus body for the purpose of approving American National Standards.
subgroup A unit established to address recurring topics or functions specific to a subcommittee. A subgroup is established by the NBIC Committee. Subgroup actions are reported to the subcommittee for approval.
task group A unit established to address a specific topic. A task
group may be established by the NBIC Committee, subcommittee or subgroup.
Project Manager Individual assigned the responsibility for developing, monitoring and responding to technical items. 4.0 Committee Structure
The committee structure consists of the NBIC Committee, subcommittees, and subgroups appointed by the NBIC Committee and task groups appointed by the NBIC Committee, a subcommittee or subgroup. The duties, responsibilities and administration of each are described below. 4.1 NBIC Committee
4.1.1 Responsibilities:
The NBIC Committee is responsible for: a. approving new rules and revising existing rules of the
Code and voting on such additions and revisions;
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b. approving interpretations of the rules of
the Code;
c. hearing requests for reconsideration regarding interpretations and revisions to the Code;
d. acting on any matter related to the scope of the Code as may be assigned by the Board.
4.1.2 Membership:
The NBIC Committee shall consist of not more than twenty-six (26) voting members within the interest categories described in paragraph 4.5. a. At least one individual representing manufacturers
shall be employed by a manufacturer of safety relief devices.
b. At least one individual representing National Board Certificate Holders shall be employed by an organization holding a valid “R” Certificate of Authorization.
c. At least one individual representing National Board Certificate Holders shall be employed by an organization holding a valid “VR” Certificate of Authorization.
d. Not more than one-third of the total NBIC Committee membership shall represent any single category of interest. The chair and vice chair of the NBIC Committee are considered within this membership. The secretary is a member of the NBIC Committee without vote.
e. Each member of the NBIC Committee may recommend a person, within the same interest category, as a representative to serve in the absence of the member at a specific meeting. Representatives have the same privileges and responsibilities as the member when serving in the member’s capacity.
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The representative’s involvement terminates at the conclusion of the specific meeting requested by the member.
f. NBIC Committee members, uUpon change of employment status affecting the member’s category of interest, NBIC Committee members shall notify the NBIC Committee secretary and will be deemed to have submitted their resignations from the NBIC Committee. Reappointment to the NBIC Committee shall follow the requirements of paragraph 4.1.3.
4.1.3 NBIC Committee Member Selection, Approval and Term
a. A candidate for appointment or reappointment as a voting member of the NBIC Committee is selected by a majority vote of the NBIC Committee membership. The candidate’s name is then submitted to the Chairman of the Board for consideration. All voting members of the NBIC Committee must be appointed by the Chairman of the Board.
b. A candidate for appointment or reappointment as the NBIC Committee Chair or Vice Chair is selected by a majority vote of the NBIC Committee membership. The candidate’s name is then submitted to the Chairman of the Board for consideration. The chair and vice chair must be appointed by the Chairman of the Board.
c. The NBIC Committee secretary is selected by the Executive Director of the National Board and is considered to be a non-voting member of the NBIC Committee without any interest affiliation.
d. The term of all voting members is three (3) years.
Voting members are eligible for reappointment.
e. The term for the chair and vice chair is the same as their NBIC Committee membership expiration date. The chair and vice chair are eligible for renewal of their terms of office.
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f. A candidate for membership on the NBIC Committee must provide a work history/resume to the NBIC Committee secretary.
4.2 Subcommittees
4.2.1 Responsibilities
Subcommittees are responsible for: a. maintaining (adding new requirements, revising
existing requirements) those sections of the NBIC that are assigned to the subcommittee.
b. acting on requests for interpretations of the rules for
those assigned sections of the NBIC;
c. acting on any matter related to the scope of the NBIC as may be assigned by the NBIC Committee;
d. forwarding all subcommittee actions to the NBIC
Committee.
4.2.2 Membership
a. The number of members appointed to each subcommittee shall be as necessary to carry on the assigned responsibility. The size of subcommittees will be limited to numbers which will best serve operational needs.
b. Each member of the NBIC subcommittee may
recommend a person, within the same interest category, as a representative to serve in the absence of the member at a specific meeting. Representatives shall have the same privileges and responsibilities as the member when serving in the member’s capacity. The representative’s involvement automatically terminates at the conclusion of the specific meeting requested by the member.
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c. NBIC subcommittee members, uUpon change of employment status affecting the member’s category of interest, NBIC Subcommittee members shall notify the NBIC Committee secretary and will be deemed to have submitted their resignations from the subcommittee. Reappointment to the NBIC Subcommittee shall follow the requirements of paragraph 4.2.3.
4.2.3 Subcommittee Member Selection, Approval and Term
a. A candidate for appointment or reappointment as a
voting member of the subcommittee is selected by majority vote of the NBIC Committee membership. Subcommittee members need not necessarily be members of the NBIC Committee or subgroup. The candidate’s name is then submitted to the Chairman of the Board for consideration. All voting members of the subcommittee must be appointed by the Chairman of the Board.
b. Candidates for appointment or reappointment as the subcommittee chair and vice chair are selected by a majority vote of the subcommittee membership. The candidate’s names are then submitted to the Chairman of the Board for consideration. The chair and vice chair must be appointed by the Chairman of the Board.
c. The subcommittee secretary is a member of the subcommittee without vote and is selected by the Executive Director of the National Board.
d. The term for all voting members is three (3) years.
Voting members are eligible for reappointment.
e. The term for the chair and vice chair is the same as their subcommittee membership expiration date. The chair and vice chair are eligible for renewal of their terms of office.
f. A candidate for membership on the subcommittee must provide a work history/resume to the NBIC Committee secretary.
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4.3 Subgroups
4.3.1 Responsibilities
Subgroups are responsible for: a. developing new rules and revising existing rules for
specific Code sections or paragraphs;
b. acting on requests for interpretations of the rules for specific Code sections or paragraphs;
c. acting on any matter related to the scope of the Code
as may be assigned by the committee or subcommittee;
d. forwarding all subgroup actions to the subcommittee, as appropriate
4.3.2 Membership
The number of members appointed to each subgroup shall be as necessary to carry out the assigned work. The size of subgroups will be limited to numbers to best serve operational needs.
4.3.3 Subgroup member selection, approval and term
a. A candidate for appointment or reappointment as a
member of the subgroup is selected by the majority vote of the subcommittee membership. Subgroup members need not necessarily be members of the Committee or subcommittee. The candidate’s name is then submitted to the Chairman of the Board for consideration. All voting members of the subgroup must be appointed by the Chairman of the Board.
b. Candidates for appointment or reappointment as subgroup chair and vice chair are selected by a majority vote of the subcommittee membership. The chair and vice chair of each subgroup shall be appointed by the NBIC Committee Chair.
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c. The subgroup secretary is selected by the Executive Director of the National Board and is a member of the subgroup without vote. In the absence of a selected secretary, the subgroup chair may appoint a voting member of the subgroup to act as secretary.
d. The term for all voting members is for three years. Voting members are eligible for reappointment. e. The term for the chair or vice chair is the same as their membership expiration date and these positions are eligible for renewal. f. The name of a National Board Member who is a
candidate to serve on a subgroup, but is not a member of the NBIC Committee or a subcommittee, must be submitted to the Chairman of the Board for approval.
g. A candidate for membership on a subgroup must provide a work history/resume to the NBIC Committee secretary.
4.4 Task Groups
4.4.1 Responsibilities
Task groups are responsible for: a. developing new rules and revising existing rules for
specific Code topics or paragraphs;
b. acting on requests for interpretations of the rules for specific Code topics or paragraphs;
c. acting on any matter related to the scope of the Code
as may be assigned by committees d. forwarding all task group actions to the committee as
appropriate.
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4.4.2 Membership
The number of members appointed to each task group shall be as necessary to carry out the assigned task. The size of task groups will be limited to numbers which will best serve operational needs.
4.4.3 Task Group Member Selection, Approval and Term
a. When the committee agrees on the need or at the discretion of the chair of a committee, a task group, members, and chair shall be appointed by the committee chair. A member of the task group may be appointed as task group secretary by the task group chair. Task group members need not necessarily be members of a committee.
b. The name of a National Board Member who is a candidate to serve on a task group, but is not a member of the NBIC Committee or a subcommittee, must be submitted to the Chairman of the Board for approval.
c. The task group will be dismissed once the task has been
completed or at the discretion of the chair of the committee.
4.5 Interest Categories 4.5.1 NBIC Committee, subcommittee, subgroup and task group
members shall not be considered as representing any specific organization. Participation by individuals employed by governmental agencies or affiliated with industry is not to be interpreted as government or industry endorsement. Membership shall be selected from the categories of interest listed below.
a. General Interest: Individuals who are not employed by an organization characterized by b through h shall be considered General Interest.
b. Manufacturers: Any organization accredited by ASME
to hold an ASME Code symbol stamp.
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c. Authorized Inspection Agency: An authorized (insurance) inspection agency recognized by the National Board.
d. Jurisdictional Authorities: National Board members.
e. National Board Certificate Holders: Repair
organizations accredited by the National Board to hold “R”, “NR” or “VR” certification.
f. Users: Owners or users of boilers/pressure vessels.
g. Labor: Individuals representing labor organizations
whose members are skilled workers in boiler or pressure vessel manufacturing or repairing, such as the United Association of Journeymen and Apprentices of Plumbing and Pipe Fitting Industry of the United States and Canada or the International Brotherhood of Boilermakers, Ship Builders, Blacksmiths, Forgers and Helpers.
h. Regulatory Authorities: Representatives of US
Governmental agencies that regulate boilers or pressure vessels or both.
4.5.2 Lack of any particular representative of any interest category at a
meeting shall not preclude the committee from conducting its business when a quorum is present.
5.0 Duties of NBIC Committee, Subcommittee, Subgroup and Task Group
Membership
5.1 Chair
The chair shall preside at meetings of the committee and shall perform other duties as are customarily assigned to that position.
The chair of the NBIC Committee shall make an annual review of the activity of each voting member of the NBIC Committee, subcommittee and subgroup with regard to the member’s contribution to the work, attention to correspondence, and attendance at meetings. Based on this review, if a consistent lack of attendance or participation within the past year is noted, the chair may recommend to the Chairman of the Board that the
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member’s appointment to the NBIC Committee be terminated. The chair’s report of NBIC Committee member’s activities shall be sent to the Chairman of the Board and the Executive Director of the National Board.
5.2 Vice Chair
The vice chair shall, in the absence of the chair, fulfill the duties of the chair.
5.3 Secretary
In addition to the responsibilities required by this procedure, the Secretary shall prepare agendas and record minutes of meetings and shall perform such other duties as are customarily assigned to such an office. In the absence of the chair and vice chair at a meeting, the secretary shall take the chair for the purpose of receiving nominations from the members present for election of a chair pro tem, who shall then preside at the meeting.
5.4 Members
The duty of each member is to give thorough consideration to each subject brought before the committee for action, vote on acceptance or rejection of each proposal, and assist generally in carrying out the assigned functions. Such duties may be carried out by attendance at meetings, by correspondence, and by telephone.
6.0 Meetings
6.1 Scheduling Meetings NBIC Committee meetings sha ll be held at the call of the Chair, as
decided upon by a m ajority of NBIC Committee members, or as directed by the Chairman of the Board. Subcommi ttee, subgroup and task group meeti ngs held at times and locations other tha n in conjunction with t he NBIC Com mittee meeting shall require the approval of the National Boar d Executive Director. Meeting requests shall be in writing to the Executive Director and include the subcommittee, subgroup or task group members’ roster.
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6.2 Locations
The NBIC Committee shall meet in National Board member jurisdictions.
6.3 Meeting Notification
All committee meeting schedules shall be posted on t he National Board web site. The National Boar d member in whose jurisdiction the NBIC Committee is meeting shall be invited to attend the meeting.
A meeting agenda shall be made av ailable to the members prior to the meeting and shall be subject to approval at the commencement of each meeting.
6.4 Public Meetings
Meetings at which the committee co nsiders proposed revisions t o the NBIC, reaffirmation of previo usly considered revisions or withdrawal of previ ously approved revisions shall be open to t he general public. Unless matters to be discussed by t he committee are deemed to be of a confidenti al nature by the chair, committee meetings shall be open to any interested person who shall be given an opportunity to participate in the discussions on subjects of interest to them.
6.5 Quorum
Fifty-one percent of the NBIC Committee, subcommittee or subgroup voting membership eligible to vote must be present to conduct committee business.
6.6 Meeting Conduct
The committee shall conduct meetings in accordance with the latest available edition of Roberts Rules of Order (Revised) unless rules to the contrary are specified in these procedures.
6.7 Recording Meeting Proceedings
Taping of committee meetings, othe r than by the secretary, is prohibited.
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6.8 Minutes
All meetings of the NBIC Committee, subcommittees and subgroups shall be documented in minutes of the meeting. The minutes are not to be considered a verbatim record of the meeting but rather a record of the voted actions and highlights of significant discussions or conclusions. The title page of committee minutes shall include the following statements:
“These minutes are subject to approval and are for committee use only. T hey are not to be dupl icated or quote d for other t han committee use.”
Minutes of committee meetings will be distributed to the members
of the committees, the Executive Director, National Board members and Advisory Committee members, as requested. Copies of committee minutes will be made available on the National
Board’s Web site for review until the next scheduled meeting minutes are available.
7.0 Voting
7.1 General
7.1.1 Each committee member shall exercise their vote within the presented time limits. When a committee member fails to report when due, or consistently abstains from voting, the committee member’s appointm ent shall be subject to termination. T he individual may appeal such action. Committee members are encourag ed to vote as soon as possible.
7.1.2 Votes for committee actions may be obtained by letter, fax, recorded votes at meetings, or electronic means. All committee members shall have an opportunity to vote . When recorded votes are taken at meetings, the committee members who are absent shall be given t he opportunity to vote.
7.1.3 The vote of each committee memb er shall be in one of the following categories:
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Approved Disapproved Abstention Not voting (for possible conflict of interest)
A response of not voting signifies neither approval nor disapproval and should be executed only when the committee member believes that they have a conflict of interest or potential conflict of interest and is removing themselves from the voting process. Committee members casting disapproved responses should include an alternate action that will resolve their disapproved vote. Committee members casting abstained responses should include a reason for the abstention. 7.1.4 Approval of committee actions shall be by a majority vote.
Approval of the following actions of the NBIC Committee or subcommittee shall require two-thirds (2/3) majority vote of the committee membership, excluding not voting responses: or not returned ballots:
committee procedures and interest categories reaffirmation of the NBIC as an ANSI Standard NBIC revisions interpretation of the NBIC scope of the NBIC Committee or subcommittee New ANSI standard
7.1.5 Voting by NBIC Committee members not present at a meeting or by letter ballot may be obta ined by let ter, facsimile, or by other electronic means.
7.2 Voting at Meetings
NBIC Committee members not pres ent at a meet ing for final approval of Code rev isions shall be affor ded the opportunit y to submit their vote within two w eeks after the date of t he NBIC Committee meeting. It is the responsibility of the National Board to provide the information relating to the items prior to the meeting in the form of posted Agendas. Di sapproved actions at the meeting
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shall be placed on the Subc ommittee agenda for the next scheduled meeting.
7.3 Voting by Letter Ballot
7.3.1 A letter ballot on any subject re quires a response of at least fifty-one percent of committee me mbers eligible to vote and may be authorize d by the Chair of the NB IC Commi ttee, Chair of a subcommittee, Chairman of the Board, or a majority vote of those present and voting at a NBIC Committee or subcommittee meet ing. The voting period for a letter ballot may be four (4) calendar weeks; however, in order to expedite the item, this period may be shortened to no less than two calendar weeks by the person authorizing the letter ballot. Voting period s shall be closed upon receipt of all responses, but not late r than the e stablished closing date. All l etter ballots shall be coordinated by the NBIC Committee secretary.
7.3.2 At the conclusion of the le tter ballot period, the NBIC Committee or subcommittee secretary shall tally the votes and report the results to the members. The secretary shall collect the comments accompan ying votes and dist ribute these to the appropriate co mmittee for disposit ion. If approved disposition is not accomplished, the letter ballot is disapproved, the item shall be placed on the agenda f or the next meeting. All disapprove d comments shall m ay be reviewed electronically by the N BIC Committee members or subcommittee members during the letter ballot period.
The Project Manager shall respond to all negative comments received. Upon Proj ect Manager responses to negative comments, the letter ballot, with or without revisions, shall be resubmitted for a two week ti me period for members to respond, reaffirm or change their original vote. Reaffirmation does not require a response during this voting period. At the conclusion of the letter ballot period, the NBIC Committee or subcommittee secretary shall ta lly the votes and report the results to the me mbers. The Project Manage r shall communicate with negative com menters in order to r esolve their concerns, whenever possible. All negative voters shall be advised in writing of the disposition of their co mment(s) and of their right to appeal the NBIC Committee’s or subcommittee’s decision.
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NBIC Committee or subcommittee members shall be apprised of any unr esolved comments and attempts at resolution and given two (2) w eeks from notification to respond, reaffirm, or change their original vote. If th e required vote approval percentage is affir mative after this time period, the ba llot shall be considered approved. Letter ballots not approved shall be pl aced on the ag enda for the next scheduled meeting of the NBIC Committee or subcommittee.
8.0 National Board Inspection Code Publication Administration
8.1 ANSI Approval Process
The NBIC Committee is accredited by ANSI as a developer of American National Standards. The NBIC Committee, subcommittees, subgroups and task groups must conduct activities in accordance with this procedure and the current rules and procedures of ANSI. 8.1.1 Documentation
a. After the NBIC Committee has approved the revisions to be included in the e dition, the secretary shall prepare and submit a Standa rds Action Public Review Request (BSR-8) form. A notice of all revisions shall be posted on the National Board’s Web si te for publi c review and comment.
b. At the conclusion of the required comment period, the
secretary shall collect a ll comments submitte d and distribute the comments to the appropriate subcommittee.
c. The secretary shall coordinate the disposition of public
review comments.
d. The disposition of all public review comments shall be approved by the NBIC Committee.
e. The commenter shall be advised, in writing, of the
disposition of the comment and the commentator’s right to appeal the NBIC Committee’s decision.
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f. All NBIC Committee members sh all be notified of all
unresolved comments and att empts at resolution to afford all members an opportunity to respond, reaffirm or change their vote.
g. Resolutions involving substantive changes to appr oved
text shall be resubmitted for public review at the next scheduled public revi ew and comment period or a new action shall be generated to address the commentators recommended change as appropriate. N o substantive changes shall be ma de to an a pproved revision unless ANSI Essential Requirements are met.
h. When the disposition of all comments has been completed, or if no comments were submitted, the secretary shall prepare and submit the Formal Submittal
Checklist for approval or withdrawal as an American National Standard (BSR-9) Form.
8.1.2 Secretariat
a. The National Board is the secretariat for the N BIC Committee. Its duties include:
1. providing administrative support for the activities of
the secretary, and 2. publishing and distributing the Code, ,
minutes, and interpretations approved in accordance with these procedures.
b. It shall be the responsibility of the secretary to:
1. ensure that the NBIC Committee adheres to these and other referenced or applicable procedures,
2. apply to ANSI for accreditation of the NBIC Committee by that organization,
3. maintain a committee roster of the members which shall include names o f the officers, and members, their address, business affilia tion, category of interest, appointment expiration date,
4. comply with ANSI requirements for the NBIC Committee administration, and
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5. submit proposed revisions to this procedure to ANSI for approval.
8.1.3 Internal Audits
At least once every three calendar years, the Executive Director of the National Board shall have an audit made of the NBIC Committee’s activities to ensure these procedures are followed. The audit shall be conducted by person(s) who are not members of the NBIC Committee. The audit report and follow-up action of def iciencies uncovered by an audit shall be reported to t he NBIC Committee and the Chairman of the Board.
8.1.4 Patent Policy
The National Board shall comply with the ANSI patent policy as described in the ANSI Essential Requirements.
8.1.5 Commercial Terms
The National Board shall comply with the ANSI Commercial Terms and Conditions Policy as described in the ANSI Essential Requirements 8.1.6 Withdrawal of an American National Standard (ANS) When required by ANSI Essential Requirements or the National Board elects to withdraw an American National Standard, the National Board shall immediately notify ANSI for announcement in ANSI Standards Action. The National Board shall comply with all ANSI Essential Requirements for withdrawal of an American National Standard.
8.2 Revisions to the NBIC
8.2.1 Any interested person may request consideration of a revision to the NBIC by submitting such request in writing to the secretary. If deemed edit orial as determined by the secretary, requests will be inco rporated into the NBIC draft edition for distribution and publ ic review. Comments which are editorial in nat ure need not be subm itted to t he NBIC Committee or subcommittees fo r consideration prior to inclusion in the edition. Any public review comments
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associated with these editoria l comments will be handled as such and will be considered by the NBIC Committee and subcommittee at the next sc heduled meetings for final approval.
Requests which are technical in nature wil l be forwarded to the appropriate subcommittee for consideration and recommendations made to th e NBIC Committ ee, for their approval. Once approved, these revisions will be incorporated into the next draf t. If approval is not reached, the item will be returned to t he subcommittee for further action.
8.2.2 Following approval of a revision by the NBIC Committee and
acceptance under AN SI procedures, the approved revision shall be published in the next edition.
8.3 Interpretations of the NBIC
8.3.1 The NBIC Committee has the responsibility for interpreting
and replying to questions concerning the application of NBIC rule or guideline. A ny interested person may request, in writing, an interpretation of a rule or guideline contained in the NBIC through the NBIC Committee secretary.
8.3.2 Upon receipt of such a request the NBIC Committee secretary determines which su bcommittee should develop a technical response. When responding to questions concerning the interpretation of a rule or guideline, the following is to be used as a response:
“The NBIC was developed unde r procedures approved by the American National Standa rds Institute. The NBIC Committee that approved the NBIC and revisions thereto is a consensus NBIC Committee balanced to assure that individuals from competent an d concerned interests have been afforded the op portunity to participate. Further, all proposed revisions to the NBIC are made available for public review and comment which provides an opportunity for additional input from juri sdictions, industry and the public at large.”
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From time to time a request for interpretation regar ding a superseded edition of the NB IC may be submitte d to the NBIC Committee. If in the opinion of the members of the NBIC Committee, a response can be formulated, the NBIC Committee should respond to the inquirer's question. However, when it is the co nsensus of the NBIC Committee that a response cannot be formulated, the NBIC Committee should respond as follows:
“The (edition of the NBIC) has been superseded. The historical knowledge that t he NBIC Committee feels is needed to respond to your re quest for interpretation is no longer available to the NBIC Committee.”
8.3.3 All interpretations of the NBIC shall be approved by the NBIC
Committee.
8.3.4 All interpretations of the NBIC shall be posted on the
National Board web site. A written response will also be sent to the inquirer.
8.3.5 The National Board accepts responsibility for, and recognizes only those interpretations approved by the NBIC Committee.
8.4 Publications
8.4.1 NBIC
The NBIC shall be identified as "An American National Standard" and "ANSI/NB-23" in accordance with ANSI procedures.
A new edi tion of t he NBIC shall be p ublished every two years. Each edition shall have a date of issue. T he NBIC may be used beginning with the date of issue. Six (6) months after the date of issue, the editio n becomes the requirement for compliance with NBIC.
Complimentary copies of the NB IC will be provi ded to the members of the NBIC Committee and subcommittees.
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8.4.2 Forms
National Board forms are part of the standard and follow the same requirements for revision as outlined in this procedure.
8.5 General 8.5.1 Referencing Other Standards
When the NBIC Committee wishes to reference another code or standard, the date of the specific, referenced code or standard shall not be cited unless required.
8.5.2 Copyrights
Copyright and all rights in all materials produced by the committee are owned by the National Board.
9.0 Due Process
The National Board provides due pro cess for t he impartial handling of complaints regarding procedural or technical issues for any action or inaction. As part of this due process there are several levels to w hich an aggrieved party may appeal. This section gives criteria regarding right t o appeal, how appeals are made and what may be appealed.
At any level of the appeal process, there shall be no informal disc ussions between the bo dy hearing the appe al and repre sentatives of the appellant. Persons who have directly and materially affected interests and who have been or will be adversely affected by any procedural or technical action or inaction with regard to the developm ent of a proposed American National Standard or the revision, reaffirmation or withdrawal of the NBIC have the right to appeal. Appeals shall be addressed promptly and a decision made expeditiously. The following process shall be followed:
a. Any person aggrieved by an interpretation, disposition of c omments,
procedural or technical issues may appeal to the NBIC Committee. b. The aggrieved person shall f irst request reconsideration by the NBIC
Committee. Such r equest shall be in writing, addressed to the NBIC
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Committee secretary, and shall st ate the reasons for requesting reconsideration.
c. Should the person remain aggrieved following such reconsideration by
the NBIC Committee or should such reconsideration be denied, the aggrieved person then, in writi ng, addressed to the National Board’s Executive Director, may request revi ew by the National Board Appeals Committee.
The findings of the National Board Appeals Committee operating under their procedures, shall be binding on the NBIC Committee as to the specific item under appeal and it shall be incumbent upon t he NBIC Committee to c onsider incorporating the National Board Appeals Committee findings.
d. Should the person remain aggrieved following the National Board Appeals Committee’s decision, further appeal may be taken to the
Board. Such appeal is initiated by a written request, addressed to the National Board’s Executive Director setting forth the grounds for such appeal. The appeal shall be heard at the next regular or special meeting of the Board which is held at a time of sufficient duration following such request as to allow distribution of all relevant documents and materials to the Board members. The Board, upon considering such appeal, by affirmative majority vote of those present, may allow a variance, may direct the NBIC Committee to consider a revision, or may sustain the action of the National Board Appeals Committee. The decision of the Board of Trustees on such appeal shall be final.
10.0 Records
Records shall be retained for a minimum of five (5) years or until approval of the subsequent revision or reaffirmation of the complete standard. Records for withdrawn standards shall be retained for a minimum of 5 years after withdrawal or until the next ANSI audit, whichever is longer. H:\ROBIN-Active Documents\NBIC Secretarial Documents\Procedures\Internal Procedures\Internal Procedures\NB-240 Rev. 12.docx
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