Meeting of July 16, 2014 Columbus, Ohio

Transcription

1 Date Distributed: July 31, 2014 NATIONAL BOARD INSPECTION CODE COMMITTEE Meeting of July 16, 2014 Columbus, Ohio MINUTES 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 Phone: (614) FAX: (614)

2 1. Call to Order - 8:00 a.m. Chairman Don Cook called the meeting to order at 8:00 a.m. 2. Introduction of Members/Visitors The Committee members and visitors introduced themselves. 3. Announcements Mr. David Douin, Executive Director of the National Board handed out two service awards. Mr. Frank Hart was presented with a plaque acknowledging him for his many years of service. He is retiring and this will be his last meeting. Mr. Don Cook was presented with a ten year pin to commemorate his 10 years of involvement with the NBIC Committee. Mr. Robert Schueler was acknowledged for his years of service on the Locomotive subgroup. He is retiring at the end of. Mr. Bill Smith was also acknowledged for his years of service as the Subcommittee Inspection secretary. Ms. Jodi Metzmaier will be assuming the position of secretary. 4. Adoption of the Agenda These minutes reflect the order the items were taken during the meeting but not the order as written in the agenda. All items in the agenda were addressed during the meeting and are recorded in these minutes. Mr. Cook announced that the action items on the agenda will be taken by those items that were approved by each Subcommittee first and then all of the progress reports would be given following. The following action items were added to the agenda: SC Installation: NB Part 1, S3.5 Change the last sentence in this paragraph to read: The required warning sign shall be shown in Figure S3.5 NB Part 1, Address the term feedwater pump in this section. NB Part 1, 1.5, 1.6, Remove the word local from these parts to avoid confusion as to what local jurisdiction means. SC Inspection: NB Resolve minor changes in text in Part 2 SC Repair and Alteration: NB TR 3 Form Page 2 of 16

3 NB Reference to TR accreditation There was a motion to approve the agenda as modified. The motion was unanimously approved. 5. Approval of the Minutes There was a motion to approve the minutes from the January Mr. Wielgoszinski had one minor change. The motion was unanimously approved as amended. 6. Review of Rosters/Resignations/Nominations/Reappointments (Attachment 1) a. Changes to rosters The following individuals are the proposed Chairs and Vice Chairs for the newly consolidated Subgroups: Part 1 Installation: Chair Melissa Wadkinson, Vice Chair Don Patten Part 2 Inspection Chair Jim Getter, Vice Chair Mike Schwartzwalder Part 3 Repair and Alteration Chair- Angelo Bramucci, Vice Chair To be determined after first meeting. b. Resignations Mr. Frank Hart is retiring at the end of and has submitted his resignation from the NBIC Committees. c. Nominations and reappointments for NBIC Committee members, Subcommittee members and subgroups that serve all four subcommittees. There was a motion to reappoint Messrs. Ralph Pate, Paul Bourgeois, Jim Riley, James Sekely and Benjamin Anthony to the NBIC Committee pending the approval of the Chairman of the BOT. The motion was unanimously approved. There was a motion to reappoint Mr. Raymond McCaffery to the SC on PRD pending the approval of the Chairman of the BOT. The motion was unanimously approved. There was a motion to appoint Mr. Rob Troutt as a member of the Subcommittee on Repairs and Alterations pending the approval of the Chairman of the BOT. The motion was unanimously approved. 7. Report of Subcommittees a. Subcommittee on Installation (Attachment 2) 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 Page 3 of 16

4 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 NB Part 1 S3 - Expand the section on installation of thermal fluid heaters. This action item is a result of splitting NB into two parts. A task group of D. Patten (PM), M. Wadkinson, G. Halley, G. Scribner and P. Bourgeois has been assigned. (Attachment 2, pp ) Ms. Wadkinson reported with proposed wording. The item had gone out to the NBIC and PRD Committees for comment only. Ms. Wadkinson addressed all comments received in an attachment to the agenda. The Committee members that commented were polled to see if there concerns were addressed. All commenters stated they were satisfied with Ms. Wadkisnon s responses. There was a motion to approve this document. The motion was unanimously approved. NB Part , SG PVP Revise wording in this section concerning pressure rating for drain pipe, valves, and fittings. This item is a result of an received by Mr. Francis Brown concerning this paragraph. (Attachment 2, pp ) Mr. Patten reported with proposed wording. There was a motion to approve the proposed wording. The wording changed the pressure rating to what is stated in B31.1. The motion was unanimously approved. NB Part 1, Section 1 Scope SC on Installation The scopes throughout Part 1 need to be revised. This item pertains to Part 1, Section 1. (Attachment 2, p. 29) Mr. Edward Wiggins presented a scope for Part 1, Section 1. There had not been a scope there previously, only an introduction. There was a motion to approve the new wording. The motion was unanimously approved. NB Part 1, Section 2, SC on Installation - The scopes throughout Part 1 need to be revised. This item pertains to Part 1, Section 2. (Attachment 2, p. 30) Mr. Wiggins reported with proposed wording. The proposed wording is more consistent with the other parts scopes. There was a motion to approve the new wording. The motion was unanimously approved. NB Part 1, Section 3 Scope SC on Installation - The scopes throughout Part 1 need to be revised. This item pertains to Part 1, Section 3.(Attachment 2, p. 31) Mr. Wiggins reported with proposed wording. The proposed wording is more consistent with the other parts scopes. There was a motion to approve the new wording. The motion was unanimously approved. Page 4 of 16

5 NB Part 1, Section 4 Scope SC on Installation - The scopes throughout Part 1 need to be revised. This item pertains to Part 1, Section 4. (Attachment 2, p. 32) Mr. Wiggins reported with proposed wording. The proposed wording is more consistent with the other parts scopes. There was a motion to approve the new wording. The motion was unanimously approved. NB Part 1, Section 5 Scope SC on Installation - The scopes throughout Part 1 need to be revised. This item pertains to Part 1, Section 5. (Attachment 2, p. 33) Mr. Wiggins reported with proposed wording. The proposed wording is more consistent with the other parts scopes. There was a motion to approve the new wording. The motion was unanimously approved. NB Part 1, S3.5 SG on PVP - Address CO 2 low level alarm. This item is a result of action Item NB A TG of P. Bourgeois (PM), E. Wiggins, M. Washington and D. Patten was assigned. (Attachment 2, pp ) Mr. Patten reported with proposed wording. The IFC has approved a lower level of ppm to trigger vessel failure in CO2 tanks so the current wording in the book needs to be revised to meet this change. There was a motion to approve the new wording. The motion was unanimously approved. NB Part 1, SC Installation - Address the term feedwater pump in this section. (Attachment 2, pp ) Mr. Don Patten reported with proposed wording that changed feedpump to feedwater pump throughout this section. There was a motion to approve this change. The motion was unanimously approved. NB Part 1, 1.5, 1.6, SC Installation - Remove the word local from these parts to avoid confusion as to what local jurisdiction means. (Attachment 2, pp ) Ms. Wadkinson reported with a proposed text change to delete the word local in these sections to avoid potential public review comments. There was a motion to approve this text change. The motion was unanimously approved. NB Part 1 S3.5 SC Installation - Change the last sentence in this paragraph to read: The required warning sign shall be shown in Figure S3.5 (Attachment 2, p. 40) There was a motion to accept this wording revision. The motion was unanimously approved. b. SC on Inspection (Attachment 3) 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. Page 5 of 16

6 Membership: Mark Mooney (Chair), Tim Barker, Domenic Canonico, Mark Horbaczewski, Jim Getter, Greg McRae, Venus Newton, Ralph Pate, Bob Reetz, Jim Riley, Jason Safarz, Mike Schwartzwalder, Stan Staniszewski, and Bill Smith (Secretary). Mr. Mooney reported on the following: NB Part 2, , SG Inspection Specific - Replacement of stamping during inservice inspection. (Attachment 3, pp ) Mr. Mooney reported with proposed wording. This wording had gone out to letter ballot for comment only following the January 2014 meeting. The comments received were addressed during this meeting. There was a motion to approve this wording. The motion was approved with one disapproved vote. NB 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) Mr. Mooney reported with proposed wording. The proposal included lengthy wording that was questioned by various committee members. There was a motion to approve the wording. The motion failed with the following results: 8 approved, 8 disapproved and 5 abstentions. The wording will be sent back to the SC Inspection for more work. NB 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. (Attachment 3, pp ) Mr. Mooney reported with proposed wording. The wording was lengthy and could not be sufficiently reviewed during the meeting. There was a motion to letter ballot the main committee. The motion was unanimously approved. NB Part 2 S10.6 SC on Inspection - In Part 2, Section S10.6 the last sentence of the first paragraph currently reads "The warning signs shall be as follows".the proposal would change the above sentence to read "The required warning sign shall be as shown in Figure S10.6". (Attachment 3, p. 47) Mr. Mooney reported with a proposed wording change. There was a motion to approve the wording. The motion was unanimously approved. NB Part 2, Clarification of previously approved 2015 action items.. After a staff review of the 2015 Cycles A, B, and C potential sources of public review comments were identified. In order to avoid these potential comments, staff extracted these items for revision prior to the document being sent out for public review. (Attachment 3, p. 48) Mr. Mooney presented this item in three different parts. Page 6 of 16

7 A. Part 2, a)-1- PVHO s must be constructed in accordance with ASME PVHO-1 and inspected in accordance with ASME PVHO-2. B. Part 2, f) 3) Change the wording to read: the sum of the dimensions (depth and width) along any straight line within any 50 sq. inches (32000 sq.mm) area does not exceed 2 in. (50 mm). C. Part 2, S.9.1 Strike the word local before jurisdiction. There was a motion to approve these wording changes. The motion was unanimously approved. c. SC on Repairs and Alterations (Attachment 4) 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, Paul Edwards, Craig Hopkins, Wayne Jones, Jim Larson, Lawrence McManoman, Jim Pillow, Bryan Schulte, Jim Sekely, Mike Webb and Bill Vallance (Secretary). G. Galanes is reported on the following: NB Part 3, , SG on R/A Specific - Tube plugging for fire tube boilers. (Attachment 4, p. 49) Mr. Bramucci reported with proposed wording. This wording had been sent to the NBIC Committee for comment only and Mr. Bramucci made some modifications as a result. There was a motion to approve the propose wording. The motion was approved with one abstention. NB 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 (Attachment 4, pp ) There was a motion to close this item. Mr. Galanes stated that the work has already been done on this item and that it was already given to the National Board staff. There was a motion to approve closing this item. The motion was unanimously approved. NB Part 3, f), f), 2.5. SG on R/A Spec.- Revise NBIC Part 3, f), f), f) and d) located in Alternative Welding Methods. (Attachment 4, pp.56-57) Mr. Galanes reported with proposed wording. This wording is exempting the temper bead requirement. There was a motion to approve this wording. The motion was unanimously approved. NB Part 3, Figure a SG on R/A Gen.- Typical examples of seal welding tubes. This figure does not provide the precautions for examining for cracking as in b seal welding of riveted joints. (No attachment) There was a motion to close this item with no action taken. The Committee felt that the wording Page 7 of 16

8 would be too redundant. The motion was unanimously approved. NB Part 3, S SG on R/A Spec. Definition of seal weld. (Attachment 4, p.58) Mr. Galanes reported with a proposed definition. There was a motion to approve the wording. The motion was unanimously approved. This definition will appear in the Glossary. d. Subcommittee on PRD (Attachment 5) 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), Marianne Brodeur, Sid Cammeresi, Kim Beise, Alton Cox, Denis DeMichael, Robert Dobbins, Robert Donalson, David McHugh, Raymond McCaffrey, Brandon Nutter, Thakor Patel, Adam Renaldo, Kevin Simmons and Tom Beirne (Secretary). Mr. Hart is reported on the following: NB Part 3, S7.14.2, Spring-Loaded PRVs SC on PRD - Revise wording in this chart. (Attachment 5, pp ) Mr. Hart reported with a revised chart. There was a motion to approve the chart as presented. The motion was unanimously approved. e. SC Installation Progress Reports NB Part 1 SC Installation - Request for a format change to NBIC Part 1 Code Rules. A task group of M. Wadkinson (PM), B. Moore, S. Konopacki, D. Patten and E. Wiggins was assigned (No attachment) Ms. Wadkinson reported that the TG was identifying common language and formatting throughout Part 1. Topics such as lighting and ventilation are being identified so that they can all be placed in the same area of the document. NB 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) Mr. Richards reported that he had spoken with Mr. Francis Brown regarding this action item and he stated that they are still working on it. NB 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) Mr. Brian Moore reported that the task group is focusing primarily on mobile wound healing Page 8 of 16

9 chambers and the concerns that are common among users. NB Part 1, SG Boilers - Addition of installation requirements for condensing hot water boilers. A TG of G. Halley (PM), P. Bourgeois, M. Wadkinson, D. Patten and B. Moore has been assigned. (No attachment) Mr. Halley reported that the had a break out session on Tuesday and that they are continuing to work on the item. NB Part 1, SG Boilers Index proofing. A TG of B. Moore (PM), M. T. Creacy, K. Watson and M. Washington is assigned. (No attachment) Richards, Mr. Moore gave a report that he had set a deadline for October 1, 2014 for task group members to submit new words for the index in Part 1. He also stated that Mr. Scribner has already completed the index for Part 1 and is just looking for input from the task group. NB Part 1, e) SG PVP - This item is a result of action item NB This text needs to be revised due to this wording passage. (No attachment) Mr. Bourgeois reported that they task group is focusing on electrical safety requirements for indirect heaters. The task group will continue to work on this for the next meeting. f. SC Inspection Progress Reports NB 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) Mr. Staniszewski reported with a written statement on the progress of this item. The Public Review Comment period has ended. These comments need to be addressed. Following this the Federal Registry should be able to make reference to the NBIC 2013 Edition and ASME Section XII. NB 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) Mr. Reetz reported that Mike Wahl is finding more errors as they research this item. They are trying to fix them as they are found but have identified at least 6 that need to be corrected. NB 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) Mr. Newton reported that CO 2 is complete and the task group is now working on heating boilers. NB Part j) 1) SG Inspection General - Revise wording to clarify the rule in this section. (Attachment 3, p. 44) Page 9 of 16

10 Mr. Riley reported that when reviewing this item it was found that some of this wording exists in other parts of the book and it was confusing as written. There was a motion to close this item and open a new item, NB , to address this topic. The motion was unanimously approved. NB 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) Mr. Reetz reported that this item needs to be moved to Part 3. NB 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. (Attachment 3, pp ) Mr. Jim Larson reported that the task group has a preliminary report for firing historical boilers with liquid or gas. The Subgroup is developing wording to be added to this section.. NB Part 2, , SG Inspection General - This action item is a result of PRC PR 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 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 was assigned. (Attachment 3, p. 47) Mr. Mooney reported there was no action on this item, NB 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 is assigned. (Attachment 3, pp ) Mr. Jim Riley reported that in the last 6 months they have met with several FEA practitioners and they all report that the AI s do not have the knowledge or skill set to inspect these vessels. The task group is developing a new section for Part 2 where the inspector must review calculations for fitness for service and that their findings must be validated by a Professional Engineer with FEA certification. NB Part 2, SG Inspection General - Review Cryogenic vessel inspection requirements. A Task Group consisting of J. Riley (PM), A. Renaldo, R. Dobbins, R. Bartley, J. Getter and R. Pate was assigned. (No attachment) Mr. Riley reported that this would be a new section in the book on the inspection of static vacuum cryogenic vessels. This is a general assessment of installations and what is being done to ensure safety. A list of items that need to be inspected will also be included. This will also include the consideration for doing a vacuum test every 8-15 years. Page 10 of 16

11 NB B - Part 2, SG on LB Fillet welded staybolts. (Attachment 3, p. 43) Mr. Reetz gave a progress report. He stated that this item has not been viewed by the subgroup at this time. NB Part 2, SG on LB Method for analyzing bulges created by overheating in stayed boiler surfaces. (Attachment 3, pp ) Mr. Reetz gave a progress report. He stated that subgroup has not reviewed this item. NB Part 2, SG Insp. Spec. Inspection requirements of wire wound pressure vessels. (Attachment 3, p. 66) Mr. Mooney stated that this item will be letter balloted by the Subgroup. NB Part 2 Update index to Part 2. A Task Group consisting of D. Canonico and M. Mooney was assigned. (No attachment) Mr. Mooney stated that the TG is accepting any additional terms. NB Part 2, SG Inspection Specific Inspection of High Pressure Vessels (Attachment 3, pp, 67-70) Mr. Mooney reported that there was no action on this action item. He stated that he would contact Mr. Francis Brown for more direction. NB Part 2, SG Insp. Spec. - The NBIC does not address replacement of duplicate nameplates where the original nameplate is intact and attached to an inner vessel and may or may not be visible. (Attachment 3, p. 71) Mr. Mooney reported that the task group is still working on this. NB Part 2, SG on Insp. Spec. - Add diagrams for Local Thin Areas (LTA) for LP Gas and propane tanks. (No attachment) Mr. Mooney state that a task group of G. McRae, J. Getter and T. Vandini was assigned. NB Part 2, 6.1 SC on Inspection-Paragraph 6.1 is a scope for the supplement section. This is the only part that has this. It is not consistent with our formatting and is a repeat of what is covered in the Introduction under Supplements in all three parts. (No attachment). Mr. Mooney stated that a task group of. D. Canonico, M. Mooney and D. Graf was assigned. Page 11 of 16

12 g. Subcommittee Repair and Alteration Progress Reports. 1) Inquiries IN Part 3, 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 d) 1)? Reply: No (Attachment 4, pp ) Mr. Marty Toth reported with proposed wording. After much discussion it was moved to approve the proposed question and reply. The motion was unanimously approved. IN Part 3, 1.2 SC on R and A - 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. 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. (Attachment 4, pp ) Mr. Wielgoszinski reported that a task group of himself (PM), Walt Sperko and George Galanes has been assigned.. IN Part 3 PWHT SC on R and A - Subject: NBIC 2010, part 3, Post Weld Heat Treatment of a Vessel. Q1. Must a company that performs post weld heat treatment be required to hold an R certification? ANS: YES Q2. Is this post weld heat treatment now considered an Alteration to this vessel, as per NBIC part 3? ANS: YES Q3. Shall this Alteration be documented on a NBIC R-2 form? ANS: YES (No attachment) Mr. Galanes reported that a task group of W. Sperko (PM), B. Wielgoszinski and himself has been assigned. 2) Action Items NB Part 3, SG R/A Specific-Repair and Alteration of Gasketed PHE s in the field. (No attachment) Mr. Pillow reported that the task group is waiting for action to take place in ASME Section XII regarding rules on this type of repair. Page 12 of 16

13 NB Part 3, S.9.2, SG LB - Add wording in this section regarding boiler tube welding. (No attachment) Mr. Reetz stated that this item has not been reviewed by the Subgroup on Locomotive Boilers. NB Part 3, S1.9.2 SG LB - Installation of Boiler and Arch Tubes. (No attachment) Mr. Reetz stated that this item has not been reviewed by the Subgroup on Locomotive Boilers. NB A - Part 3 S1, SG LB - Fillet welded staybolts. (No attachment) Mr. Reetz reported that this item has not been reviewed by the subgroup on Locomotive Boilers. NB Part 3, S1.2.9 SG LB - Throttle pipes, dry pipes, superheater headers and front end steam pipes. (No attachment) Mr. Reetz reported that this item has been approved by the subgroup on Locomotive Boilers and is ready to be letter balloted to the SC Repair and Alteration. NB Part 3, S1, SG LB - Superheater units. (No attachment) Mr. Reetz reported that this item has been approved by the subgroup on Locomotive Boilers and is ready to be letter balloted to the SC Repair and Alteration. NB Part 3, S1 SG LB Bolts, nuts and studs. (No attachment) Mr. Reetz reported that this item needs to be letter balloted to the subgroup. NB Part 3, S1 SG LB- Threaded boiler studs-taper thread and straight thread types. (No attachment) Mr. Reetz reported that this item needs to be letter balloted to the subgroup. NB Part 3, 1.5, SG R/A General - 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) Mr. Paul Edwards reported that the task group is cleaning up the references in the document. NB Part 3, and SG R/ A Specific- This item is a result of IN Write rules for encapsulation. (No attachment) Page 13 of 16

14 Mr. Galanes gave a progress report. NB Part 3, S6.15 SG on R/A Spec. Development of TR Forms. (No attachment) Mr. Galanes reported that the forms are being developed by Bill Vallance, the SC R/A secretary. NB Part 3, c) SG on R/A Gen. This action item is a result of IN 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) Mr. Wielgoszinski reported that he has developed wording for review and comment. NB Part 3, S6 - SC R/A - Development of a TR3 form. Mr. Staniszewski reported that the newtr form will be very similar to the existing R form that is currently in the book. NB Part 3, S6 SC RA Adding accreditation requirements to S6. Mr. Galanes reported that wording is being worked on to reference accreditation in this section. h. Subcommittee PRD progress reports 1) Inquiries IN SC on PRD Part3, QUESTION: Does the second sentence of NBIC Part 3, , i.) Repair procedures shall require verification that the critical parts meet the valve manufacturer s specification require a VR Certificate Holder to use the current Original Manufacturer s Spring Chart in the repair of Pressure Relief Valves? ANSWER: Yes. (Attachment 5, p. 103) Mr. Hart reported that the subcommittee has spoken with the inquirer and decided to open an action item NB to address his concerns. IN Part 3, SC on PRD Question-Does the statement in NBIC Part 3, , d) 1) b. Have been disassembled, inspected, and repaired by the Certificate Holder such that the valves condition and performance are equivalent to the standards for new valves permit the use of outdated Spring Charts to repair PRVs without replacing the existing spring even though the current OEM Spring Chart calls for a different number? ANSWER: No. (Attachment 5, p.104) Mr. Hart reported that the subcommittee has spoken with the inquirer and decided to open an action item NB to address his concerns. Page 14 of 16

15 2) Action Items NB Part 4, SC PRD - The development of a possible fourth part of the NBIC to cover pressure relief topics. (No attachment) Mr. Hart reported that all committees had been asked to review the latest revisions of Part 4 and that numerous comments had been received. As a result of this several new action items had been opened to address these comments. NB Part 3, SC on PRD - Prepare a guide for repair of tank vents. (No attachment) Mr. Hart reported that Mr. Denis DeMichael is in the process of collecting manufacturer s recommended procedures for repairs of vent valves NB 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) Mr. Hart gave a progress report. NB Index SC on PRD - Update glossary of all three parts.a task group of Benjamin Anthony and Marianne Brodeur were assigned to Part 1, Denis DeMichael, Buddy Dobbins and Bob Donalson were assigned to Part 2, Brandon Nutter, Raymond McCaffery, Thakor Patel and Kevin Simmons were assigned to Part 3. Mr. Hart stated that the the task group is continuing to work on this but is awaiting the completion of part 4 to finish. NB Part 3, i), b)2), c) SC on PRD - Review of Records Retention Requirements. (No attachment) Mr. Hart stated that a task group of Buddy Dobbins (PM) Kim Beise and Adam Renaldo has been assigned. 8. Liaison Activities a. ASME- Paul Edwards reported with a handout of new developments in ASME. b. AWS- Jim Sekely was not present to report. c. API- Jim Riley reported with a handout of new developments in API. d. I.C.C.-Chuck Withers reported that an item is out for public review regarding solar grading standards minimum criteria for a thermal grading system. This document is posted on the NBIC Cloud for review. Page 15 of 16

16 e. PCC No report was available. Mr. Riley will work with PCC to provide a report for the next meeting. 9. New Business Mr. Cook reviewed the Web-ex training and stated that this presentation will be available on the NBIC Cloud. 10. Future Meetings The following meetings have been scheduled: January 19-23, 2015, Orlando, Florida July 21-24, 2015, Columbus, Ohio 11. Adjournment Mr. Cook adjourned the meeting at 1:54 p.m. Robin Hough Secretary, NBIC Committee E:\Minutes NBIC 0714.doc Page 16 of 16

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26 Responses to review/comment ballot of NB to Main Committee & Subcommittee Pressure Relieving Devices By M. Wadkinson 6/9/14 Name Comment Response George Galanes PE Michael Webb Gary Scribner Jim Riley Nice work on this supplement. I just have a few suggested editorial changes; 1. change exit to egress 2. under Vented; NPSH in the first line should be defined as in the second line to avoid confusing readers. I too see a few instances where the context is difficult to read such as J. Pillow identified; c. I am not sure if: " A means of disconnecting with capability of being locked..." was intended or not. There were a few others as well generically referencing "a nationally or internationally recognized e 1. What standard is being targeted? This needs a bit more work... S uses the word "should". In all other cases in part 1 this is a "shall". This should be changed to shall for consistency. A good start. A few thought provoking comments: (1) S4.3.1 and S4.3.3 I believe I have seen tfh's on offshore FPSO vessels. Any additional thought required above that which is stated for shifting vessel supports and containment? (2) S " between adjacent battery units may not be enough to provide personnel egress if one is operating and there is a problem during inspection from the side. (3) S4.5.2 drop pout of pump and burner should require 'cause and effect' consideration; burner 'yes' but should pump flow through hot heater tubes be cut or left flowing? (4) S4.5.5 welded piping should require 'full penetration butt welded joints'; if not, poor practice of Much of the text in this document utilizes the same wording already used in this part for Power Boilers, Heating Boilers and Pressure vessels. This was intentionally done for consistency. In the next draft, I will highlight the wording that is new (and specific) for thermal fluid heaters. If there is wording currently used in Part 1 that the Committee feels should be changed, I recommend a separate item to address. Please see my response to Mr. Galanes as much of the wording used in this supplement is existing text in Part (c) is wording consistent with CSD 1 and with item NB which added this wording to Part e 1 is consistent with wording already used in Section 2 and Section 3 of Part 1. UL is an example of a nationally recognized standard. I will make that change. (1) (2) In my experience, 18 is sufficient space between the units. Typically there is nothing that needs to be accessed/inspected on the sides of the heaters. (3) If there is an insufficient fluid level in the expansion tank, the pump can cavitate and air can be drawn into the system. It is preferable to shut down the burner and the pump in this situation. Drawing air into the system can cause further complications including fluid degradation. By shutting down the burner and the pump NBIC Part 1 would be consistent with NFPA 87 recommendations. (4) A statement requiring full penetration welds can be added to Page 10 of 60

27 James Pillow Domenic Canonico Bob Reetz Robert Wielgoszinski slamming ends together and buttering around the abutment may lead to leaks or injuries from failed welds. The "disapproved" is based on what appears to be an incomplete sentence in the first line of c. The remaining comments are editorial. Scope Do we need all the caps? Definitions Suggest putting in alpha order and use "Thermal Fluid A fluid...", etc can probably delete "hard". Also add metrics f De we need the caps? d Is "egress" the correct word. This means exit. Why not just use "exit"? e.2.c Delete first "on the". I am confused about what is the intent of this ballot, what is being changed and what is being added and/or subtracted. This new section deals with thermal fluid heaters. It does not deal with thermal fluid vaporizers. (ASME treats thermal fluid heaters as Section VIII units. Thermal fluid vaporizers are built to Section I, Part PVG.) Therefore, in S4.7.1 (a) I would remove "or vapor service" and I would note in S4.8.5 that an installation report is only required for those jurisdictions that require these units to be handled as boilers and require an ASME Section I designation. In S4.2 there is a definition of thermal fluid vaporizer. Is this definition only provided so the user knows the the text. (1) Regarding the first line of (c), the wording consistent with CSD 1 and with item NB which added this wording to Part 1. (2) Scope: I will remove the caps and restructure the paragraph (3) will delete the word hard (4) F I will remove the caps (5) d the wording is consistent with that already used in Section 2 and Section 3 of Part 1. (6) e 2 c I will make that change The entire supplement is new to Part 1. Much of the text in this document utilizes the same wording already used in this part for Power Boilers, Heating Boilers and Pressure vessels. This was intentionally done for consistency. In the next draft, I will highlight the wording that is new (and specific) for thermal fluid heaters. If there is wording currently used in Part 1 that the Committee feels should be changed, I recommend a separate item to address. Much of the proposed text is applicable for vapor phase thermal fluid systems as well as liquid phase. Liquid phase heaters have a wider application than vapor phase. I propose editing the scope to cover liquid phase and after the supplement is adopted we can open an item to include vapor phase systems depending on the fluid used and the operating temperature the discharge from the pressure relief valve may be in the vapor phase therefore the wording in the text is appropriate the proposed text is consistent with that already in Section 2 and Section 3 of Part 1, however, the word should is used in lieu of shall. Much of the proposed text is applicable for vapor phase thermal fluid systems as well as liquid phase. Liquid phase heaters have Page 11 of 60

28 Brandon Nutter difference between a TFH and TFV? Or does this supplement also cover thermal fluid vaporizers? S4.7 Change title to "Overpressure Protection" S4.7.1 Correct to read S Introductory sentence is unclear and excludes the possibility of overpressure protection by system design (e.g. Section VIII, Div. 1 UG 140). Recommend re writing first sentence to read Thermal fluid heaters shall be provided overpressure protection in accordance with the code of construction. See comment on S S4.7.1 a) Replace unclear as applicable to the application with as required for the applicable service and overpressure conditions. and relocate to NEW S4.7.2 c). See incorporation in comment NEW S4.7.2 c). S4.7.1 b) Delete. Redundant to S4.7.6 d) and inconsistent with same. S4.7.1 c) Delete. Redundant to S4.7.5 and inconsistent with S4.7.5 b). S4.7.1 d) Move to NEW S4.7.2 a) S4.7.1 e) Delete. Unnecessary to list items that are not requirements. S4.7.1 g) Delete. What is the technical basis for this requirement? S4.7.2 Correct to read S4.7.2 and retitle as Pressure Relief Devices. Delete existing words and a wider application than vapor phase. I propose editing the scope to cover liquid phase and after the supplement is adopted we can open an item to include vapor phase systems. Thank you for your comments. I will incorporate many of your suggestions. Much of the text used in this section originated from text already included in Section 2, Section 3 or Section 4 of Part 1. Page 12 of 60

29 replace with Unless otherwise protected from overpressure in accordance with the code of construction, liquid thermal heaters shall be equipped with one or more pressure relief devices. {NEW S4.7.2 a)} Pressure relief valve(s) shall be of a totally enclosed type and shall not have a lifting lever. {NEW S4.7.2 b)} Rupture disks may be installed upstream or downstream of pressure relief valves in accordance with the code of construction. {NEW S4.7.2 c)} Pressure relief valves and rupture disks shall be in accordance with the code of construction and designed for liquid, vapor, or combination service as required for the specific installation, service fluids, and overpressure conditions. S4.7.4 Rewrite sentence to read The pressure relief device(s) shall have sufficient capacity to prevent the pressure vessel from exceeding the maximum pressure specified in the vessel code of construction. S4.7.5 b) Replace set pressure needs to be at in the first sentence with needs to be set at or below. In the second sentence, replace overpressure with maximum pressure. S4.7.6 Correct S4.76 to read S4.7.6 There is no need to state these are requirements. Additionally, there is no need to specify discharge piping when the section also contains (should contain) inlet piping requirements. Retitle to read Installation. Page 13 of 60

30 S4.7.6 a) Remove second part of sentence and combine with rewritten 2 nd & 3 rd sentences of S4.7.6 e) to read When a discharge pipe is used, the cross sectional area shall not be less than the full area of the valve outlet. The size of the discharge lines shall be such that any pressure that may exist or develop will not reduce the relieving capacity or adversely affect the operation of the attached pressure relief devices. Discharge piping shall be as short and straight as possible and arranged to avoid undue stress on the pressure relief device. S4.7.6 b) No guidance is given for inlet piping for single device installations. Recommend adding the following before the existing words The cross sectional area of the piping between the heater and the relief device inlet shall be sized either to avoid restricting the flow to the pressure relief devices or made at least equal to the inlet area of the pressure relief devices connected to it. S4.7.6 c) Some code sections permit stop valves under certain conditions. Recommend replacing There with Unless permitted by the code of construction, there. S4.7.6 e) Relocate 2 nd & 3 rd sentences to S4.7.6 a) as commented above and insert caution regarding safe discharge of drain effluent. Paragraph should read Discharge lines from pressure relief devices shall be designed to facilitate drainage or be fitted with low point or valve body drains to prevent liquid from collecting in the discharge side of a pressure relief device. Drain piping shall discharge to a safe location for the disposal of fluids being relieved. Denis S4.1 Thermal fluid heaters come in a variety of sizes. Is Thank you for your comments. Page 14 of 60

31 DeMichael this guidance intended to apply to all heaters? S4.5.2 What is the technical basis for requiring a pressure relief device just because the expansion tank is pressurized? Pressure relief should be provided in accordance of the code of construction used for the expansion vessel. S4.7.1 The guidance in the first sentence is not very clear. What does appropriate for the code of construction mean? Does service mean normal operating conditions or relief conditions? S4.7.1 a) What is the difference between service in the previous section and application? S4.7.1 b) This should be in S4.7.6 S4.7.1 c) This is in conflict with S4.7.5 b). S4.7.1 e) Why are we stating what isn t required? S4.7.1 g) What is the technical basis for the requirement? S4.76 should be S4.7.6 S4.7.6 a) Pipe sizes for header systems should be based on performance requirements where technical calculations are required to verify the system performance versus an area requirement that cannot be technically justified. General There are multiple references (i.e. Location, Capacity, and Set Pressure) that require compliance with the code of construction. Why not replace the whole Pressure Relief Valve section with a requirement that overpressure protection shall comply with vessel's code of construction. Only those items that are not normally addressed by the code of construction should be included. Robert Dobbins 1) The area to which Relief valve discharge piping is directed is addressed in paragraph b and again in S4.76.d. Does this point need to be made twice in two areas or can they be combined in S4.76.d? 2) g and S4.76.a seem to contradict each other to me. S4.76.a seems to allow a smaller pipe size at the discharge than is allowed in g I will incorporate many of your suggestions including clarification on compliance with the Code of Construction. Much of the text used in this section originated from text already included in Section 2, Section 3 or Section 4 of Part 1. Thank you for your comments. I will revise the paragraph. Much of the text used in this section originated from text already included in Section 2, Section 3 or Section 4 of Part 1. Page 15 of 60

32 Subgroup PV&P Subcommittee Installation NBIC Main Committee National Board Inspection Code Subcommittee Installation Subgroup on Pressure Vessels and Piping Members: NB Donald Patten Stan Konopacki Gary Scribner Melissa Wadkinson Task Group Assignment Address Thermal Fluid Heater Installation Source PR Proposal Insert the following text as Part 1, Section 6 Installation Supplements NOTE TO READERS & EDITORS: Much of the proposed text is existing wording that is already used in Part 1. This wording was used intentionally for consistency within the Sections for Power Boilers, Heating Boilers and Pressure Vessels. For wording specifically pertaining to thermal fluid heaters, (ie not already used in Part 1) I will highlight that text. I ask that if there is a comment or suggested change to the standard Part 1 text that those changes be considered under a separate item. Proposed Text S4.1 SCOPE PART 1, SECTION 6 SUPPLEMENT 4 INSTALLATION OF THERMAL FLUID HEATERS This Supplement describes guidelines for the installation of a thermal fluid heater. A thermal fluid heater system consists of the heater, expansion tank, circulating pump, safe catchment with the proper piping and controls to heat jacketed kettles, presses, reactors, ovens, exchangers, etc. The scope does not include thermal fluid vaporizers. S4.2 DEFINITION Page 1 of 11 Page 16 of 60

33 Subgroup PV&P Subcommittee Installation NBIC Main Committee Thermal fluid: a fluid (other than water) that is chemically stable over a large temperature range and is specifically designed for use as a heat transfer medium. Thermal fluid heater: a closed loop liquid phase heater (flooded pressure vessel) in which the heat transfer media is heated but no vaporization takes place within the vessel. Depending on the fluid selection and operating parameters, systems may be open or closed to the atmosphere. Closed systems may be pressurized with an inert gas blanket. Thermal fluid vaporizer: a heater in which the thermal fluid is vaporized within the pressure vessel. S4.3 General Requirements S4.3.1 Supports, Foundations, and Settings Each thermal fluid heater and its associated piping must be safely supported. Design of supports, foundations, and settings shall consider vibration (including seismic where necessary), movement (including thermal movement), and loadings (including the weight of the fluid in the system) in accordance with jurisdictional requirements, manufacturer s recommendations, and/or other industry standards, as applicable. S4.3.2 STRUCTURAL STEEL a) If the thermal fluid heater is supported by structural steel work, the steel supporting members shall be so located or insulated that the heat from the furnace will not affect their strength. b) Structural steel shall be installed in accordance with jurisdictional requirements, manufacturer s recommendations, and/or other industry standards, as applicable. S4.3.3 SETTINGS The thermal fluid heater shall be installed on a flat, level, non combustible surface preferably of concrete to protect against any fire hazard. A 4 containment curb or 2 seal welded drip lip around the thermal fluid heater equipment skid shall be provided. S4.3.4 CLEARANCES a) Thermal fluid heater installations shall allow for normal operation, maintenance, and inspections. There shall be at least 18 in. (457 mm) of clearance on each side of the thermal fluid heater to enable access for maintenance and/or inspection activities. Thermal fluid heaters operated in battery shall not be installed closer than 18 in. (457 mm) from each other. The front or rear of any thermal fluid heater shall not be located nearer than 36 in. (915 mm) from any wall or structure. b) Vertical heaters shall have at least 60 in. (915 mm) clearance from the top of the heater or as recommended by the heater manufacturer. c) Heaters with a bottom opening used for inspection or maintenance shall have at least 18 in. (350 mm) of unobstructed clearance. Page 2 of 11 Page 17 of 60

34 Subgroup PV&P Subcommittee Installation NBIC Main Committee d) NOTE: Alternative clearances in accordance with the manufacturer s recommendation are subject to acceptance by the Jurisdiction. S.4.4 THERMAL FLUID HEATER ROOM REQUIREMENTS S EXIT Two means of exit shall be provided for thermal fluid heater rooms exceeding 500 sq. ft. (46.5 sq. m) floor area and containing one or more thermal fluid heaters 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 thermal fluid heater is not considered an elevation. S LADDERS AND RUNWAYS a) All walkways, runways and platforms shall be: 1) Of metal construction 2) Provided between or over the top of heaters 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 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; 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. Page 3 of 11 Page 18 of 60

35 Subgroup PV&P Subcommittee Installation NBIC Main Committee d) There shall be at least two permanently installed means of exit from walkways, runways, or platforms that exceed 6 ft. (1.8m) in length. S4.5 SYSTEM REQUIREMENTS S4.5.1 THERMAL LIQUIDS (HEAT TRANSFER FLUIDS) It is extremely important that the proper heat transfer fluid be selected by competent personnel knowledgeable of the system. Heat transfer fluids should meet the following basic requirements: a) Resist deterioration at the temperatures involved, to assure long useful life and a clean system. b) Possess good heat transfer characteristics. c) Have low vapor pressures at operating temperatures to permit operation at moderate pressures. Note: processes requiring thermal fluid temperatures higher than 650 F will require the use of specialty fluids with high vapor pressures (e.g. 150 psi). These fluids also tend to have special environmental, safety and health considerations. d) Have low viscosities to decrease pumping losses (due to pipe friction) and the power required for circulation. e) Be suitable for outside temperatures involved to prevent freeze up unless a means of heat trace has been implemented. f) Meet environmental regulations. The heat transfer fluid must be kept clean and in proper condition. Tests of the fluid shall be conducted per the fluid manufacturer s recommendations by approved laboratories. Any heat transfer fluid that is added must be clean and of the proper specification. S4.5.2 EXPANSION The expansion tank shall have sufficient volume to handle the required expansion of the total system thermal liquid at the required operating temperature. The expansion tank should be sized so that when the thermal liquid in the system is cold, the tank will be one quarter full or as recommended by the manufacturer. When the system is up to operating temperature, the level of fluid in the expansion tank shall not exceed the manufacturer s recommendation. A high expansion tank liquid level alarm may be used for indication of high liquid level in the expansion tank(s). An expansion tank low level switch (or similar device) shall be used to ensure the appropriate minimum level of fluid in the tank per the manufacturer s recommendation. Tripping of this switch should shut down the pump and burner. The activation of this switch should activate an audible alarm and/or light. All expansion tank vents and drains shall be piped to a safe catchment or per the manufacturer s recommendations. If the expansion tank is to be pressurized with an inert gas, pressure relief shall be provided in accordance with the code of construction used for the expansion vessel. When a safety relief valve is used, it shall be piped to a safe catchment. Page 4 of 11 Page 19 of 60

36 Subgroup PV&P Subcommittee Installation NBIC Main Committee S4.5.3 CONNECTION The circulating pump shall be piped to the thermal fluid heater per the manufacturer s recommendations. The expansion tank should be installed at an elevation above all piping when possible. If the tank is not at the highest elevation, an inert gas blanket shall be used to pressurize the system to overcome the weight of the fluid above the tank. a) Vented The expansion tank shall accommodate the NPSH requirements of the circulating pump to provide a Net Positive Suction Head (NPSH) for the circulating pump. For nonpressurized tanks, a vent connection (open to the atmosphere) is part of the design and should be piped to a safe catchment with no valve in the piping. b) Pressurized The expansion tank may be pressurized with nitrogen or other inert gas as recommended by the fluid manufacturer and provisions made to provide a continuous recommended pressure. The pressure may be adjusted to meet the Net Positive Suction Head requirement of the circulating pump. Compressed air is not recommended as it oxidizes the thermal fluid. Carbon Dioxide is not recommended as it dissolves into the fluid and can create cavitation or other problems in the system. S4.5.4 CIRCULATING PUMP It is essential that the pump selection be made by competent personnel that are knowledgeable to the requirements of the specific system. Special attention to hot and cold alignment requirements and pump cooling requirements must be considered. The circulating pump must: a) Provide the required fluid flow across the heater tube surface. b) Handle the Total System Head. c) Be specifically designed to handle the thermal fluid at the high temperatures as well as the viscosity requirements of cold start conditions. The pump should be rated for the maximum operating temperature of the fluid. A strainer should be located in each pump suction piping. Globe valves or other throttling valves should be considered in the pump discharge piping to throttle the pump if necessary to prevent it from running out on its curve. Dual pumps are often installed to provide 100% redundancy in the case of a pump failure. A flexible connection in and out of each pump is recommended. S4.5.5 PIPING AND VALVES Carbon Steel Pipe such as SA 53 or SA 106 is preferred for the entire piping system. Seamless pipe should be used for thermal fluid piping. Copper, copper alloys, brass, bronze, aluminum or cast iron should not be used as they are incompatible with most thermal fluids. All joints and connections Nominal Pipe Size (NPS) 1 (25 mm) and over (within the flow circuit) should be welded or flanged. Full penetration welds shall be used in the piping. All flange gaskets shall be suitable for the operating Page 5 of 11 Page 20 of 60

37 Subgroup PV&P Subcommittee Installation NBIC Main Committee temperature, pressure and fluid used. Special attention shall be given to the expansion of the piping due to the high temperatures involved. Valves shall be of steel material compatible for the thermal fluid and temperatures and shall be flanged or weld type manufactured from cast or forged steel or ductile iron. Valve internals and gland seals shall be made from materials suitable for use with high temperature fluids and compatible with the specific fluid utilized in the system. When 2 way valves are utilized in the piping system, a back pressure regulating valve or automatic bypass valve shall be incorporated to ensure the proper flow through the heater at all times regardless of control valve position. If 3 way valves are used, balancing valves should be included. Design of piping supports should be in accordance with jurisdictional requirements, manufacturer s recommendations and/or other industry standards as applicable. Thermal insulation used on the pipes and equipment should be selected for the intended purpose and for compatibility with the fluid. Where there is the potential for fluid system leaks (flanged joints etc.), the thermal insulation selected should be non absorbent. Laminated foam glass or cellular glass (nonabsorbent, closed cell) insulation are examples of suitable insulation. S4.5.6 FUEL Fuel systems, whether firing on oil, gas or other substances, shall be installed in accordance with jurisdictional and environmental requirements, manufacturer s recommendations, and/or other industry standards, as applicable ELECTRICAL a) All wiring for controls, heat generating apparatus, and other appurtenances necessary for the operation of the thermal fluid heater(s) should 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) 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. d) If the equipment room door is on the building exterior, the shutdown switch shall be located just inside the door. If there is more than one door to the equipment room, there shall be a shutdown switch located at each door of egress. 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. For power burners with detached auxiliaries, only the fuel input supply to the firebox need be shut off. e) Controls for Heat Generating Apparatus 1) Oil and gas fired and electrically heated thermal fluid heaters shall be equipped with suitable primary (flame safeguard) safety controls, safety limit switches and controls, and burners or electric elements by a nationally or internationally recognized standard. Page 6 of 11 Page 21 of 60

38 Subgroup PV&P Subcommittee Installation NBIC Main Committee 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. Thermal fluid heater shall have: a. Expansion tank low level switch liquid level switch (or similar device) interlocked with the circulating pump operation to confirm minimum level in the expansion tank when the system is cold. This interlock prevents pump cavitation. The function of this device shall prevent burner and pump operation if the liquid level is not adequate. b. Thermal fluid temperature operation control. This temperature actuated control shall shut down the fuel supply when the system reaches a preset operation temperature. This requirement does not preclude the use of additional operation control devices when required. c. High temperature limit safety switch located on the thermal fluid heater outlet. This limit shall prevent the fluid temperature from exceeding the maximum allowable temperature of the specific fluid. The high temperature limit safety switch set point should be set no higher than the maximum temperature specified by the fluid manufacturer, heater designer or downstream process limits, whichever is lowest. Functioning of this control shall cause a safety shutdown and lockout. The manual rest may be incorporated in the temperature limit control. Where a reset device is separate from the temperature limit control, a means shall be provided to indicate actuation of the temperature sensing element. Each limit and operating control shall have its own sensing element and operating switch. d. Primary flame safety control for each main burner assembly. This control shall deenergize the main fuel shut off valve and shut off pilot fuel upon loss of flame at the point of supervision. The function of this control shall cause a safety shutdown and lockout. e. Power burners and mechanical draft atmospheric burners shall provide for the preignition purging of the combustion chamber and flue passes. The purge shall provide no fewer than four air changes or greater as specified by the manufacturer. f. Proof of flow interlock thermal fluid heaters require a minimum flow rate to ensure proper velocities and film temperatures through the heater. A low flow condition can cause overheating, degradation of the fluid or heater coil or tube failure. Activation of this interlock shall cause a safety shutdown of the burner and pump. One or more interlocks shall be provided to prove minimum flow through the heater at all operating conditions. 3) In accordance with jurisdictional and environmental requirements, manufacturer s recommendations, and/or other industry standards, as applicable, Thermal fluid heaters may also have : a. A high stack temperature switch interlock in the event of a high stack temperature (indication of improper combustion or cracked coil) this device shall shut off the burner and circulating pump and cause a lockout condition. Page 7 of 11 Page 22 of 60

39 Subgroup PV&P Subcommittee Installation NBIC Main Committee b. An inert gas smothering system (steam or CO2) this system is used to quench combustion in the event of a cracked heater coil or tube. The gas smothering system should be installed per local codes and requirements. A typical system may include two stack limit switches, an alarm and valve to allow inert gas to enter the combustion chamber. One stack limit is set at a value above the typical stack temperature for the equipment (1000 deg. F) and the second is set at 100 deg. F above the first. If the limit is tripped, the pump and burner will shut down. If the second limit is tripped, the inert gas shall enter the combustion chamber to quench the flame. c. A high inlet pressure switch this normally closed switch senses pressure at the heater inlet and its setpoint is determined based on the system design pressure when the system is cold. Activation of this switch indicates a restriction in flow and should shutdown the burner and pump and cause a lockout condition. d. A low inlet pressure switch this normally open switch senses pressure at the heater inlet and its setpoint is determined based on system pressure when the system is operating at temperature. Activation of this switch indicates a restriction in flow and should shutdown the burner and pump and cause a lockout condition. e. A high outlet pressure switch this normally closed switch senses pressure at the heater outlet and its setpoint is determined based on the system pressures when the system is at operating temperature. Activation of this switch indicates a restriction in flow and should shutdown the burner and pump and cause a lockout condition. Note: the setpoint of this switch should be lower than the safety relief valve setting. 4) These devices shall be installed in accordance with jurisdictional and environmental requirements, manufacturer s recommendations, and/or industry standards, as applicable. S4.5.8 VENTILATION AND COMBUSTION AIR a) The equipment room shall have an adequate air supply to permit clean, safe combustion, minimize soot formation, and maintain a minimum of 19.5% oxygen in the air of the equipment room and sufficient to maintain ambient temperatures as recommended by the heater manufacturer. 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 equipment room, or as specified in the National Fire Protection Association (NFPA) standards for oil and gas burning installations for the particular job conditions. The heater equipment 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 ( cu meters per minute) for each 1000 Btu/hr (293 W) of maximum fuel input for the combined burners of all thermal fluid heaters located in the equipment room. Additional capacity may be required for any other fuel burning equipment in the equipment room. Pressure in the room should be consistently neutral. 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 (b) may be reduced when special engineered air supply systems approved by the Jurisdiction are used. Page 8 of 11 Page 23 of 60

40 Subgroup PV&P Subcommittee Installation NBIC Main Committee f) Care should be taken to ensure that thermal fluid lines are not routed across combustion air openings, where freezing may occur in cold climates. 1 Fans When combustion air is supplied to the thermal fluid heater 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 equipment room must still be considered. S4.5.9 LIGHTING The equipment room should be well lighted and it should have an emergency light source for use in case of power failure. S EMERGENCY VALVES AND CONTROLS All emergency shut off valves and controls shall be accessible from a floor, platform, walkway, or runway. Accessibility 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. S4.6 DISCHARGE REQUIREMENTS S4.6.1 CHIMNEY OR STACK Chimneys or stacks shall be installed in accordance with jurisdictional and environmental requirements, manufacturer s recommendations, and/or industry standards, as applicable. S4.6.2 DRAINS A suitable low point drain fitted with a stop valve shall be provided in the heater or connecting piping to allow the heat transfer media to be drained out of the pressure vessel and/or piping when necessary. The valve may either be locked in the closed position or a blank flange can be installed downstream of the valve. The valve should never be opened when there is temperature on the system. S4.6.3 AIR VENT A manual air vent valve should be installed on the high point of the system piping. This valve is typically used when filling or draining the system. The valve should never be opened when there is temperature on the system or when a pressurized system is utilized. S4.7 OVERPRESSURE PROTECTION S4.7.1 GENERAL Thermal fluid heaters shall be provided with overpressure protection in accordance with the code of construction. S4.7.2 PRESSURE RELIEF DEVICES Thermal fluid heaters shall be equipped with one or more pressure relief devices unless the option for overpressure protection by system design is utilized (when permitted by the original code of construction). When pressure relief devices are used, the following shall apply: a) Pressure relief valve(s) shall be of a totally enclosed type and shall not have a lifting lever. Page 9 of 11 Page 24 of 60

41 Subgroup PV&P Subcommittee Installation NBIC Main Committee b) Rupture disks may be installed upstream or downstream of the pressure relief valve(s) in accordance with the original code of construction. c) Pressure relief valves and rupture disks shall be in accordance with the code of construction and designed for liquid, vapor, or combination service as required for the specific installation, service fluids, and overpressure conditions. d) The inlet connection to the valve shall be not less than NPS ½ (DN 15). S4.7.3 LOCATION a) Pressure relief devices shall be connected to the heater in accordance with the original code of construction. S4.7.4 CAPACITY a) The pressure relief device(s) shall have sufficient capacity to prevent the pressure vessel from exceeding the maximum pressure specified in the vessel code of construction. S4.7.5 SET PRESSURE a) When a single relief device is used, the set pressure marked on the device shall not exceed the maximum allowable working pressure. b) When more than one pressure relief device is provided to obtain the required capacity, only one pressure relief device set pressure needs to be set at or below the maximum allowable working pressure. The set pressure of the additional relief devices shall be such that the pressure cannot exceed the maximum pressure permitted by the code of construction. S4.7.6 INSTALLATION a) When a discharge pipe is used, the cross sectional area shall not be less than the full area of the valve outlet. The size of the discharge lines shall be such that any pressure that may exist or develop will not reduce the relieving capacity or adversely affect the operation of the attached pressure vessel relief devices. Discharge piping shall be as short and straight as possible and arranged to avoid undue stress on the pressure relief device. b) The cross sectional area of the piping between the heater and the relief device shall be sized either to avoid restricting the flow to the pressure relief devices or made at least equal to the inlet area of the pressure relief devices connected to it. c) When two or more required pressure relief devices are placed on one connection, the inlet cross sectional area of this connection shall be sized either to avoid restricting the flow to the pressure relief devices or made at least equal to the combined inlet areas of the pressure relief devices connected to it. d) Unless permitted by the code of construction, there shall be no intervening stop valve between the vessel and its pressure relief device(s), or between the pressure relief device and the point of discharge. e) Pressure relief device discharges shall be arranged such that they are not a hazard to personnel or other equipment and, when necessary, lead to a safe location, such as a catchment tank, for the disposal of fluids being relieved. f) Discharge lines from pressure relief devices shall be designed to facilitate drainage or be fitted with low point or valve body drains to prevent liquid from collecting in the discharge side of a pressure relief device. Drain piping shall discharge to a safe location for the disposal of the fluids being relieved. S4.8 TESTING AND ACCEPTANCE Page 10 of 11 Page 25 of 60

42 Subgroup PV&P Subcommittee Installation NBIC Main Committee S4.8.1 GENERAL a) Care shall be exercised during installation to prevent loose weld material, welding rods, small tools, and miscellaneous scrap metal from getting into the thermal fluid system. Where possible, an inspection of the interior of the thermal fluid heater and its appurtenances shall be made for the presence of foreign debris prior to making the final closure. b) Safe operation should be verified by a person familiar with heater system operations for all heaters and connected appurtenances and all pressure piping connecting them to the appurtenances and all piping. c) In bolted connections, the bolts, studs, and nuts shall be marked as required by the original Code of Construction and be fully engaged (e.g., the end of the bolt or stud shall protrude through the nut). d) Washers shall only be used when specified by the manufacturer of the part being installed. S4.8.2 Pressure Test Prior to initial operation, the completed thermal fluid heater system, including pressure piping, pumps, stop valves, etc., shall be pressure tested in accordance with the manufactures recommendations. Hydrostatic testing of the system is not recommended due to possible contamination of the system. All pressure testing should be witnessed by an Inspector. S4.8.3 Nondestructive Examination Thermal fluid heater components and subcomponents shall be nondestructively examined as required by the governing Code of Construction. S4.8.4 System Testing Prior to final acceptance, an operational test shall be performed on the complete installation. The test data shall be recorded and the data made available to the jurisdictional authorities as evidence that the installation complies with the provisions of the governing code(s) of construction. This operational test may be used as the final acceptance of the unit. S4.8.5 Final Acceptance A thermal fluid heater may not be placed into service until its installation has been inspected and accepted by the appropriate jurisdictional authorities. S4.8.6 Installation Report a) Upon completion, inspection, and acceptance of the installation, the installer should complete and certify the Boiler Installation Report I 1. See b) The Boiler Installation Report I 1 should be submitted as follows: 1) one copy to the Owner; and 2) one copy to the Jurisdiction, if required. Page 11 of 11 Page 26 of 60

43 NB 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: PRESSURE RATING a) When the maximum allowable working pressure of the boiler is equal to or less than 100 psig (700 kpa), the drain pipe, valve, and fittings shall be rated for at least 100 psig (700 kpa) and 220 F (104 C). b) When the maximum allowable working pressure of the boiler exceeds 100 psig (700 kpa), the drain pipe, valve, and fittings shall be rated for at least the maximum allowable working pressure and temperature of the boiler. b) Statement of Need Provide a brief explanation of the need for the revision or addition. Comment questioning the clarity of a) Commenter referenced B (E). Sub group reviewed both documents and decided to use B (E) verbatim and remove both a) and b). Page 27 of 60

44 NB 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 PRESSURE RATING a) When the maximum allowable working pressure of the boiler is equal to or less than 100 psig (700 kpa), the drain pipe, valve, and fittings shall be rated for at least 100 psig (700 kpa) and 220 F (104 C). b) When the maximum allowable working pressure of the boiler exceeds 100 psig (700 kpa), the drain pipe, valve, and fittings shall be rated for at least the maximum allowable working pressure and temperature of the boiler. Drain piping from the drain connection, including the required valve(s) or the blanked flange connection, shall be designed for the temperature and pressure of the drain connection. The remaining piping shall be designed for the expected maximum temperature and pressure. Static head and possible choked flow conditions shall be considered. In no case shall the design pressure and temperature be less than 100 psig ( kpa (gage)) and 220 F (l05104 C), respectively. Page 28 of 60

45 NB SCOPE NBIC Part 1 provides requirements for the installation of power boilers, steam heating boilers, hot-water heating boilers, hot-water supply boilers, potable water heaters, pressure vessels and piping. Page 29 of 60

46 NB SCOPE NBIC Part 1, Section 12 provides requirements for the installation of power boilers. as defined in NBIC Part 1, 2.2, Definitions. For installation of items that do not fall within the scope of NBIC Part 1, Section 1, refer to the applicable Sections of NBIC Part 1: Section 3 - Steam Heating Boilers, Hot-Water Heating Boilers, Hot-Water Supply Boilers, and Potable Water Heaters Section 4 - Pressure Vessels Section 5 - Piping Page 30 of 60

47 NB SCOPE The scope of NBIC Part 1, Section 3 shall apply to those steam heating boilers, hot-water heating boilers, hot-water supply boilers, and potable water heaters. as defined in NBIC Part 1, 3.2, Definitions. For installation of items that do not fall within the scope of this Section, refer to the applicable sections: NBIC Part 1, Section 2 - Power Boilers NBIC Part 1, Section 4 - Pressure Vessels NBIC Part 1, Section 5 - Piping Page 31 of 60

48 NB SCOPE NBIC Part 1, Section 4 provides requirements for the installation of pressure vessels. as defined in NBIC Part 1, Section 9 Definitions. For installation of items that do not fall within the scope of this Section, refer to the applicable Section: NBIC Part 1, Section 2 - Power Boilers NBIC Part 1, Section 3 - Steam Heating Boilers, Hot-Water Heating Boilers, Hot-Water Supply Boilers, and Potable Water Heaters NBIC Part 1, Section 5 - Piping Page 32 of 60

49 NB SCOPE NBIC Part 1, Section 5 provides requirements for the installation of pressure piping. For installation of items that do not fall within the scope of this Section, refer to the applicable Sections: NBIC Part 1, Section 2 - Power Boilers NBIC Part 1, Section 3 - Steam Heating Boilers, Hot-Water Heating Boilers, Hot-Water Supply Boilers, and Potable Water Heaters NBIC Part 1, Section 4 - Pressure Vessels Page 33 of 60

50 NB Action Item Request Form 8.3 CODE REVISIONS OR ADDITIONS Request for Code revisions or additions shall provide the following: NBIC Part 1 Supplement 3 This is resulted from the SubGroup PVP Meeting NB Task Group: Project Manager Paul Bourgeois Ed Wiggins Milton Washington Don Patten Existing Text: S3.4 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. Alarms will be designed to activate a low level pre alarm at 1.5% concentration of CO2 and a full high alarm at 3% concentration of CO2 which is the NIOSH & ACGIH 15 minute Short Term Exposure Limit for CO2. These systems are not designed for employee personal exposure monitoring. Gas detection systems shall be installed and tested in accordance with manufactures installation instructions and the following requirements: S3.5 SIGNAGE a) Activation of the gas detection system shall activate an audible alarm within the room or area in which the carbon dioxide storage vessel is located. b) Audible alarms shall also be placed at the entrance(s) to the room or area where the carbon dioxide storage vessel and/ or fill box is located to notify anyone who might try to enter the area of a potential problem. 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: a) Carbon Dioxide Monitors for general area monitoring (not employee personal exposure monitoring) are provided in this area. These monitors are set to alarm at 15,000 ppm (1.5% concentration) for the low level alarm and at 30,000 ppm (3% concentration) for high level alarm. b) Low Level Alarm (15,000 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. Page 34 of 60

51 NB b) Statement of Need Provide a brief explanation of the need for the revision or addition. This is to be consistent with the ICC Fire Codes. 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. S3.4 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. Alarms will be designed to activate a low level pre alarm at 5,000 ppm1.5% concentration of CO2 and a full high alarm at 30,000 ppm 3% concentration of CO2 which is the NIOSH & ACGIH 15 minute Short Term Exposure Limit for CO2. These systems are not designed for employee personal exposure monitoring. Gas detection systems shall be installed and tested in accordance with manufactures installation instructions and the following requirements: a) Activation of the gas detection system shall activate an audible alarm within the room or area in which the carbon dioxide storage vessel is located. b) Audible alarms shall also be placed at the entrance(s) to the room or area where the carbon dioxide storage vessel and/ or fill box is located to notify anyone who might try to enter the area of a potential problem. S3.5 SIGNAGE 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: a) Carbon Dioxide Monitors for general area monitoring (not employee personal exposure monitoring) are provided in this area. These monitors are set to alarm at 15,0005,000 ppm (1.5% concentration) for the low level alarm and at 30,000 ppm (3% concentration) for high level alarm. b) Low Level Alarm (15,000 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. Page 35 of 60

52 NB 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: Page 19 PART PUMPS a) Boiler feedwater pumps shall have discharge pressure in excess of the boiler rated pressure (MAWP) in order to compensate for frictional losses, entrance losses, regulating valve losses, and normal static head, etc. Each source of feedwater shall be capable of supplying feedwater to the boiler at a minimum pressure of 3% higher than the highest setting of any safety valve on the boiler plus the expected pressure drop across the boiler. The following table is a guideline for estimating feed pump differential: Table Guide for Feedpump Differential Page 34 Part Tables and Figures a) NBIC Part 1, Table Guide for Feed Pump Differential b) Statement of Need Provide a brief explanation of the need for the revision or addition. To remain consistent with the book the word used is feedwater pump. Change the three related items within the book to read feedwater pump. Page 36 of 60

53 NB 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. Page 19 PART PUMPS a) Boiler feedwater pumps shall have discharge pressure in excess of the boiler rated pressure (MAWP) in order to compensate for frictional losses, entrance losses, regulating valve losses, and normal static head, etc. Each source of feedwater shall be capable of supplying feedwater to the boiler at a minimum pressure of 3% higher than the highest setting of any safety valve on the boiler plus the expected pressure drop across the boiler. The following table is a guideline for estimating feedwater pump differential: Table Guide for Feedwater ppump Differential Page 34 Part Tables and Figures a) NBIC Part 1, Table Guide for Feedwater Pump Differential Page 37 of 60

54 NB 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: 1.5 Change of Service See NBIC Part 2, Supplement 9 for requirements and guidelines to be followed when a change of service or service type is made to a pressure retaining item. Whenever there is a change of service, the local jurisdiction where the pressure retaining item is to be operated, shall be notified for acceptance, when applicable. Any specific jurisdictional requirements shall be met. 1.6 Change of Service Supplement 9 provides requirements and guidelines to be followed when a change of service or service type is made to a pressure retaining item. Whenever there is a change of service, the local jurisdiction where the pressure retaining item is to be operated, shall be notified for acceptance, when applicable. Any specific jurisdictional requirements shall be met Change of Service See NBIC Part 2, Supplement 9 for requirements and guidelines to be followed when a change of service or service type is made to a pressure retaining item. Whenever there is a change of service, the local jurisdiction where the pressure retaining item is to be operated, shall be notified for acceptance, when applicable. Any specific jurisdictional requirements shall be met. Page 38 of 60

55 NB b) Statement of Need Provide a brief explanation of the need for the revision or addition. Remove the word local from the first sentence as it takes away from the intent of the paragraph. 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. 1.5 Change of Service See NBIC Part 2, Supplement 9 for requirements and guidelines to be followed when a change of service or service type is made to a pressure retaining item. Whenever there is a change of service, the local jurisdiction where the pressure retaining item is to be operated, shall be notified for acceptance, when applicable. Any specific jurisdictional requirements shall be met. 1.6 Change of Service Supplement 9 provides requirements and guidelines to be followed when a change of service or service type is made to a pressure retaining item. Whenever there is a change of service, the local jurisdiction where the pressure retaining item is to be operated, shall be notified for acceptance, when applicable. Any specific jurisdictional requirements shall be met Change of Service See NBIC Part 2, Supplement 9 for requirements and guidelines to be followed when a change of service or service type is made to a pressure retaining item. Whenever there is a change of service, the local jurisdiction where the pressure retaining item is to be operated, shall be notified for acceptance, when applicable. Any specific jurisdictional requirements shall be met. Page 39 of 60

56 NB In Part 1, Section S3.5, the last sentence of the first paragraph currently reads "The warning signs shall state the following". The proposal would change the above sentence to read "The required warning sign shall be as shown in Figure S3.5". Page 40 of 60

57 PROPOSED CHANGES NBIC Part 2, SECTION REPLACEMENT OF STAMPING OR NAMEPLATE DURING INSERVICE INSPECTION 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 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 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 SCOPE The following forms (5.3.2 through ) 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 41 of 60

58 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: (name of jurisdiction) (address) (telephone no.) Submitted by; (name of owner, user, or certificate holder) (address) (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 Mfg. Serial no. MAWP psi Dimensions Jurisdiction no. 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 (Name of inspector) NB Commission 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 42 of 60

59 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 ADDED 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) (Back) Page of 46 60

60 1.2 Administration Add to end of Part 2, Section 1.2 Unless otherwise specifically required by the Jurisdiction, the duties of the Inspector do not include inspection to other standards and requirements (environmental, construction, electrical, operational, undefined industry standards, etc.) for which other regulatory agencies have authority and responsibility to oversee. Proposed New Supplement for Part 2 Inspection of Biomass Fired Boiler Installations (Section 6, Supplement 9) S9.1 - Scope a) This supplement provides rules for continued inspection of biomass fired boilers and the additional equipment utilized in these installations. In this context Biomass is intended to mean various types of wood wastes, or wood byproducts. b) Many of the requirements of the earlier Sections of Part 2 are common to all boiler installations irrespective of the fuel being fired; therefore this supplement 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 inspection of the fuel handling and distribution systems, and the impact these systems may have on the pressure vessel itself. S9.2 Assessment of Installation a) A general assessment of the complete installation shall be undertaken, in terms of observable results of operating and maintenance practices. Indicators include the general boiler room cleanliness, for example significant quantities of fuel particles (dust) should not be apparent in the boiler room. b) The combustion air inlet shall be free of any debris or dust particle build up, and where moveable louvered intakes exist, the actuating mechanisms shall be clean and operate freely. Corrective action is required when non-compliance is noted. c) The flue gas venting system shall be checked for tightness, with no observable signs of leakage. Corrective action is required if leakage is noted. d) The intakes of the various fans or blowers shall be free of fuel particle build up or signs of other debris. Corrective action in terms of cleaning is required when discrepancies are noted. 1 Page 44 of 60

61 e) The fuel metering equipment and the fuel transportation system shall be free from signs of particulate or dust leakage. Corrective action in terms of cleaning and repair work is required as necessary. f) Electrical equipment and controls shall be properly protected from the ingress of dust, by ensuring that all cover plates are properly installed and all panel doors are intact, operable and closed. g) Verify that all guards for rotating equipment (shafts, bearings, drives) are correctly installed and fan inlet screens are in place. h) On the boiler, generally check for signs of potential problems, including; Water leaks Ash Leaks Condition of insulation and lagging. Casing leaks or cracks Check all safety valves for bypass and ensure the inspection plugs are capped and the drain lines are piped away from traffic areas. Missing or misaligned pieces or parts ie twisted, misaligned or bound up buck stays, missing linkage bolting. Condition of support systems Provision of Danger or Caution signs Excess vibration Excess noise. i) Verify that the Owner/User has established function test, inspection, requirements, maintenance and testing of all controls and safety devices in accordance with the manufacturer s recommendations. Verify that these activities are conducted at assigned intervals in accordance with written procedures, nonconformances which impact continued safe operation of the boiler are corrected and the results are properly documented. These activities shall be at a frequency recommended by the manufacturer, or frequency required by the jurisdiction. Where no frequencies are recommended, or prescribed, the activity should be conducted at least annually S9.3 Boiler Room Cleanliness a) While boiler room cleanliness is of primary importance in all boiler rooms it is of particular importance in biomass fired boiler rooms. Biomass can contain fine particulate, which if allowed to leak from the transportation system into the 2 Page 45 of 60

62 surrounding boiler room, will eventually be drawn into fans, resulting in the possibility of combustion air systems becoming plugged. b) Boiler rooms containing quantities of fine dusts are susceptible to fire or explosion, again emphasizing the need for high standards of cleanliness. S9.4 Emission Control Requirements a) Emission control is dependent upon the fuel being fired and the emission requirements prevailing at the location of the boiler installation. As such they are a part of the initial design and installation process, and apart from ensuring that they are kept in top working condition, so that emission requirements are not violated; there is little that can be done from the inspector s point of view. b) When Continuous Emissions Monitors (CEM s) are in use, they should be demonstrated to be functioning properly and have a current calibration sticker. c) Delta-P pressure gauges which measure the pressure drop across the various elements of the emission control system should all be functioning correctly. d) There should be no sign of erosion caused by entrained particulate matter, in any part of the breaching, ductwork, stack or the individual emission control elements. e) On systems in which the emissions control system incorporates a baghouse, appropriate fire detection and suppression systems shall be incorporated and functioning properly. 3 Page 46 of 60

63 NB S10.6 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 and the upper portion of the sign must be orange as shown in figure NBIC Part 2, Figure S10.6. The size of the lettering must be as large as possible for the intended viewing distance and in accordance with jurisdictional requirements. 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 be as shown in figure S10.6: Figure S10.6 CO2 Warning Sign : Page 1 of 1 Page 47 of 60

64 NB Clarify Part 2, e) Required measurements for evaluation of pitting corrosion shall include: 1) Depth of the pit; 2) Diameter of the pit; 3) Shape of the pit; 4) Uniformity. f) Widely scattered corrosion pits may be left in the pressure-retaining item in accordance with the following requirements: 1) Their depth is not more than one-half the required thickness of the pressureretaining item wall (exclusive of corrosion allowance); 2) the total area of the pits does not exceed 7 sq. in. (4500 sq mm) within any 50 sq. inches (32000 sq.mm); and 3) the sum of their dimensions (depth and width) along any straight line within this 50 sq. inches area does not exceed 2 in. (50 mm) S9.1 Strike the word local before jurisdiction Page 48 of 60

65 NB , Proposed Change, Part 3 Repairs and Alterations Page TUBE PLUGGING IN FIRETUBE BOILERS When the replacement of a tube in a firetube boiler is not practicable at the time the defective tube is detected, with the concurrence of the owner, Inspector, and when required, the Jurisdiction, the tube may be plugged using the following course of repair: Insert New Para. here a) The scope of work, type of plug and method of retention; whether welded or mechanical interface, shall be evaluated by the R -Certificate Holder performing the repair and reviewed with the Inspector, and when required, the Jurisdiction. b) When the method of plugging is by welding, strength calculations for the size of the weld shall be in accordance with the original code of construction. The R Certificate Holder performing this repair shall weld the plug to the tube, or to the tube sheet, or a combination of both. c) Plugging a tube in a firetube boiler is recognized as an alternative to the replacement of a firetube and may be further limited as a method of repair by the number of tubes plugged and their location; scattered or clustered. The operational effects on the waterside pressure boundary or membrane and the effects on the combustion process throughout the boiler should be considered prior to plugging. Rationale: Tube plugging is presently being performed using a variety of mechanical retention methods through driving, expanding or by welding plugs to existing tubes (sleeved or un-sleeved) or tube sheet holes when tubes are removed. Acceptance may be conditional depending on number of tubes plugged, their location; whether clustered or scattered, and a host of variables that may otherwise render an accepted practice as not viable or compromising in nature. The judgment of the Inspector, evaluation and experience of the R -Certificate Holder, and interaction with the owner and Manufacturer as needed, all represent the interests of the Industry as a viable method of repair when immediate replacement of the firetube cannot be performed; not yielding to safety. This item presents tube replacement as the most conservative method of repair, but provides considerations for tube plugging as a method of repair when NOT- Limited by the conditions paragraph c ; scattered or clustered suggesting the potential need for calculating the maximum pitch allowed by ASME Section I, PFT Reference: Interpretation NBI95-35, R-200 Definition of Terms, 1992 Edition with the 1994 Addendum. d) The boiler may be returned to service for a period of time agreed upon by the owner, the Inspector, and when required, the Jurisdiction. e) The Form R-1 shall be completed for the plugging of firetubes, identifying the means of plug retention; mechanical or by welding. Page 49 of 60