nbic committee agenda attachments attachments january... · nbic committee agenda attachments ......

NBIC Committee Agenda AttachmentsNBIC Committee Roster 12-22-16 3Melissa Wadkinson Resume 11-1-16 4Jim Getter Resume 11-1-16 7Angelo Bramucci Resume 11-1-16 8Ray Miletti Resume 11-1-16 12Randy Cauthon Resume 11-1-16 15Paul Schuelke Resume 11-1-16 17Darrell Graf Resume 11-1-16 24Jason Safarz Resume 11-10-16 26NB-240 Proposed Rev. 15 11-18-16 30IN15-0601 SC RA 7-20-16 51IN16-0801 Troutt 10-17-16 53IN16-1001 Jeang 12-19-16 54IN16-1101 Subhedar 12-19-16 55IN16-1201 Beaudoin 12-19-16 56IN16-1301 Napier 12-21-16 57IN16-1301 Napier Background Information 12-21-16 58NB12-0801 Failed Letter Ballot Comments 11-3-16 60NB12-0801 Webb Suggestions 11-3-16 61NB13-1405 10-31-13 SG Locomotive 62NB13-1405 Additional Information Stone 10-26-16 65NB13-1405 Stone Comments 10-26-16 71NB15-2210 Failed Letter Ballot Comments 12-22-16 74NB15-2210 Webb Revision 11-10-16 75NB16-0810 Troutt 10-17-16 77NB16-1302 SG Graphite Approved 7-20-16 78NB16-1303 SG Graphite Approved 7-20-16 79NB16-2602 Underwood 12-21-16 80NB16-2901 Price 10-28-16 82NB16-3001 Kincs 10-28-16 83NB16-3002 Kincs 10-28-16 84IN16-0901 Cox 10-19-16 85NB16-0603 Cox Suggestions 11-3-16 86NB16-0603 Failed Letter Ballot Comments 11-3-16 88NB16-3101 Cox 10-28-16 89NB16-3102 Cox 10-28-16 90

NB16-3201 Jorgensen 10-28-16 91IN16-0701 SC Installation 7-21-16 92NB16-0102 Failed Letter Ballot Comments 11-3-16 94NB16-0102 Webb Suggestions 11-3-16 95NB16-0903 Vallance 12-1-16 96NB16-0904 Vallance 12-8-16 98NB16-0905 Vallance 12-8-16 99NB16-2801 Moore 10-28-16 100NB16-2802 Moore 10-28-16 105NB16-2803 Moore 10-28-16 109NB16-2804 Moore 10-28-16 110NB16-2805 Moore 10-28-16 111NB16-2806 Moore 10-28-16 112NB16-2807 Moore 10-28-16 113IN16-0501 SC Inspection 7-20-16 115NB16-2808 Moore 10-28-16 116NB16-2809 Moore 10-28-16 124

National Board Inspection Code Committee Roster

NBIC Committee Roster 12-22-16Attachment

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Wadkinson - 1 -

Melissa Michaud Wadkinson, PE _____________________________________________________________________________________

Professional Experience The Fulton Companies, Pulaski New York 1994 – present Chief Engineer

Code compliance ‐ Participate with all design reviews for new products and product enhancements to ensure code compliance. Establish and audit manufacturing processes to ensure code compliance for ASME and all related standards.

Quality System – Establish and maintain quality systems and processes. Develop metric and reporting mechanisms to track and trend to support continuous improvement.

Design integrity – Maintain product and system design integrity by reviewing products and systems for technical feasibility, code approval and engineering best practices.

Technical Support – Provide employees and customers with engineering and technical support as needed, such as – vendor selection, component substitutions, code approval considerations, field code approval verifications, training on engineering best practice, and resolution of quality or warranty situations.

Product Manager Thermal Systems, I/C Division

Responsible for overall product integrity, advertising, development of marketing materials, coordination of trade shows, marketing research

Specify and coordinate the development of new products and product improvements with the R&D department

Designed, specified and provided quotations for customized engineered heat transfer systems working with representatives and OEMs to help secure sales and ensure compliance with specifications

Engineering Manager, I/C Division

Review all pressure vessel designs for compliance with ASME Code

Design review for application of heat transfer products and system integrity Sales Engineer/Project Engineer

Designed, specified and provided quotations for customized engineered heat transfer systems working with representatives and OEMs to help secure sales and ensure compliance with specifications

Provided technical training seminars for customers at their facilities or at Fulton Thermal Corporation

Manufacturing Engineer

Reviewed standard products for code compliance

Recommended product improvements for quality improvements and cost savings

Melissa Wadkinson Resume 11-1-16Attachment

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Wadkinson - 2 -

Precision Combustion, Inc. New Haven, Connecticut (1992 – 1994) Research and Development Engineer:

Developed computer simulations and experimental research programs to determine the effects of using different catalytic combinations on various substrates to promote and sustain combustion and reduce emissions levels

Created proposals to solicit and secure funding for new projects.

NSF Hazardous Waste Incineration: Lead Engineer.

Developed a computer model using detailed kinetic mechanism for the oxidation of chlorinated hydrocarbons and hydrocarbon fuels, in addition to catalyst life and durability studies.

EPA Volatile Organic Compound Destruction: Lead Engineer.

Led experimental program to design and construct a Catalytically Stabilized Thermal Combustor for investigation of the effects of operating parameters and design variables on the ability of the combustor to effectively destroy volatile organic compounds.

DOE Coal Gasification: Contributing Engineer.

Constructed and tested several different combustor designs leading to a design which educed the amount of fuel NOx produced from the combustion of propane doped with ammonia.

University of Massachusetts, Department of Chemical Engineering. Research Assistant (Fall 1990 – May 1992):

Performed research including theoretical and experimental techniques for project funded by General Electric and the Department of Energy

Applied thermochemical kinetics and Quantum‐RRK techniques to analyze reactions for pressure dependence

_____________________________________________________________________________________ Professional Societies

American Chemical Society American Society of Mechanical Engineers Beta Gamma Sigma Honor Society _____________________________________________________________________________________

Publications W. C. Pfefferle and M. M. Wadkinson, “Catalytically Stabalized Thermal Incineration”, National Science Foundation Final Report, 1994, Contract No ISI‐9002844. W. C. Pfefferle, J. R. Zurlo, M. G. Michaud and J. K. Burns, “Catalytic Combustor‐Based Coal Gasification Combined Cycle Gas Turbine System”, Department of Energy Final Report, 1993, Contract No. DE‐FG05‐92ER81340. M. G. Michaud, P. R. Westmoreland, and A. S. Feitelberg, “Chemical Mechanisms of NOx Formation for Gas Turbine Conditions”, Twenty‐fourth Symposium (International) on Combustion, 1992, pp. 8879‐887.


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Wadkinson - 3 -

___________________________________________________________________________________ Education

Professional Engineer New York State, June 2011 Masters of Business Administration, June 2001 Syracuse University, Syracuse, New York Master of Science in Chemical Engineering, September 1992 University of Massachusetts, Amherst, Massachusetts M.S. Thesis: “Microprobe Sampling of Low‐Pressure Propylene Flames and Modeling of High‐Pressure Methane/Air Flames”. Bachelor of Science in Chemical Engineering, May 1990 University of Virginia, Charlottesville, Virginia B.S. Thesis: “Corresponding States Correlation for the Volumetric Properties of Compressed Liquid and Liquid Mixtures”.


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Resume

James M. Getter

7150 St Rt 61

Sunbury, Ohio 43074

614-840-3087

Committee membership

NBIC Chair of Subgroup Inspection - Early 2000’s to present

NBIC member of Subcommittee Inspection – Early 2000’s to present

NBIC member of Historical Boilers – 2014 to present

PVMA member, past President – Mid 1990’s to present

Work Experience

Worthington Industries - Pressure Vessel and ASME Engineer May 1992 to present

Pressed Steel Tank - Pressure Vessel and ASME Engineer 1987 to 1992

Buckeye Boiler – Pressure Vessel and ASME Engineer 1977 to 1987

Jim Getter Resume 11-1-16Attachment

Attachment Page 7

Angelo C. Bramucci

63 Lighthouse Hill Road Residence: 860-687-1725 Windsor, CT 06095 email: [email protected]

SUMMARY Over 39 years’ experience in the operation, inspection, design and fabrication of boiler and pressure vessels. Quality Engineering and Loss Prevention Engineering with expertise in Boiler, Combustion Controls, Machinery, and Property Fire Protection. Experienced Senior Quality Assurance Engineer, facility operations, utilities, heavy industries, pulp and paper, Nondestructive Examination, American Society of Mechanical Engineers (ASME), American Welding Society (AWS), and National Fire Protection Association (NFPA) Codes and Standards, training program development, and instructor/facilitator. Known for a strong mechanical aptitude, creative and profitable approaches to problem solving, conducting skillful negotiations, developing strong teams, and establishing outstanding relationships with vendors and customers. Presently committee chair of the National Board Inspection Code (NBIC) Part 3, Subgroup Repairs and Alterations and committee member of Part 3, Subcommittee Repairs and Alterations.

EXPERIENCE GE Renewable Energy, Renewable Steam Plants, Windsor, CT Quality Manager 2014 - Present June 2014, Quality Manager of Alstom Power Inc., Renewable Steam Products-USA. Key responsibilities in support of the RSP US organization: 1) Development, management, and maintenance of the Unit’s QA/QC Management System to ISO 9001:2015 certification , ASME Section I & Section VIII certification and National Board R Stamp. 2) Direct support of Project specific QA/QC requirements. Manage the Quality Department for the Region / Product, including responsibility to define and implement the Quality strategy processes and tools within the Region / Product in line with those of the Renewable Power Sector and New Energy Business. Drive effective and efficient continuous improvement within the Region / Product and ensure maintenance of ISO Certification. Ensure that the defined level of Quality is measured, audited, reported on and, where necessary, define and implement action plans to address any issues.

Directly support of project tendering and execution. In the project support role, this position is responsible to drive effective quality management practices as an integral component of the overall project execution strategy, reflecting the pivotal importance of quality to achieving project financial goals and customer satisfaction. The QM collaborates with all execution functions, partners and suppliers to support early identification of potential quality issues and to influence cost-effective solutions that ensure quality reliable products.

Project Quality Manager 2012-2014 March 2012, Project Quality Manager - Senior Quality Engineer in the Heat Recovery Steam Generator (HRSG) Quality Department. Senior Quality Assurance Engineer 2006-2012 October 2006, Senior Quality Assurance Engineer in the Boiler Service Operations (BSO). Accountable for highly complex assignments in one or more of the quality technical fields such as systems, inspection, manufacturing surveillance, problem analysis, supplier evaluation, process improvement, quality planning and economic impact. Perform very broad Quality Assurance assignments of major scope and importance on an independent basis. Personnel at this level are considered experts in their major field of endeavor and will provide assistance as required to lower level Quality Engineers. Representative of Alstom as Committee Member on the National Board Inspection Code (NBIC), Subgroup, Book III Repairs & Alterations. Participated as alternate representative on ASME Section I Code Committees.

Angelo Bramucci Resume 11-1-16Attachment

Attachment Page 8

Project Quality Manager 2001-2006 June 2001, Permanent staff as a Project Quality Manager - Senior Quality Engineer in the Heat Recovery Steam Generator (HRSG) Quality Department. Developed and implemented Quality Plans in accordance to ASME, ISO/EN Standards, Pressure Equipment Directive (PED) and Canadian Standards Association (CSA). Qualified and monitor pressure parts and structure steel suppliers. Assigned as Project Quality Manager (PQM) on HRSG projects, sample of projects:

GE/TVA Contract, 2 HRSG Units CPV Contract, 5 HRSG Units Santan Expansion Contract (Salt River Project), 3 HRSG Units Alunorte Expansion Project, Brazil, 2 Circulating Fluidized Bed Boilers (CFB) Cartagena Project, Spain, 3 HRSG Units, Constructed in accordance to PED and CE Marked

Assistant Project Quality Manager (Contingent Staff) 2000 - 2001 July 2000, Responsible for assisting Project Quality Managers in the HRSG Quality Department. Carried out PQM duties, proposal reviews, project team meetings, Inspection Test Plan (ITP) development, ASME Code design reviews, ASME data package development including final review and code stamping, and monitor supplier surveillance activities.

Conducted contract proposal reviews, quality plan development and contract quality budgets. Conducted supplier alignment meetings. Supervised quality field surveillance activities and supported site code weld repairs.

Industrial Risk Insurers, Hartford, CT 1997-2000 Senior Loss Prevention Training Consultant (Authorized Inspector, A.I.) Responsible for the needs assessment, task analysis, program development, and delivery of training material for loss prevention staff and educational programs for clients and customers.

Administered Industrial Risk Insurers, Confined Space and Respiratory Protection Programs for employees meeting OSHA regulations.

Undertook the Training Center renovation project improving classroom design and up-grade of A/V equipment establishing a world class training facility.

Designed and instructed marketable programs for customers covering Property Fire Protection Systems, Boiler and Machinery Systems, and World Class Maintenance Programs.

Senior Boiler and Machinery Consultant (Authorized Inspector, A.I.) 1989 to 1997 Responsible for conducting loss prevention surveys as a resident engineer in Syracuse, New York, covering upstate New York and parts of New England. Surveys included the review of operational and maintenance procedures of production machinery, mechanical and electrical equipment of various size industrial plants, including the jurisdictional certificate inspections of boilers and pressure vessels. Conducted operational and dismantled inspections on Steam and Gas Turbines monitoring electrical testing of generators. Performed plan reviews on new construction from design, construction, and commissioning of cogeneration facilities and various industrial plants.

Designed and instructed technical programs for Industrial Risk Insurers, Boiler and Machinery and Fire Protection Consultants and for the State of Maine, annual Boiler and Pressure Vessel Seminars.

Completed large loss investigations, conducted loss analysis, determining cause of loss, contributing factors, and generated corrective recommendations.

Boiler and Machinery inspection and evaluations incorporating various nondestructive examination techniques.

Assigned as Authorized Inspector (AI) of utility facilities (gas turbines, steam, hydro).


Attachment Page 9

Instrument and Control Engineering, Agawam, MA 1988 to 1989 District Manager District Manager, covering upstate New York and eastern Ohio region. Company specialized in combustion controls and instrumentation for steam generation. Responsibilities consisted of development of product sales and service accounts, recruit, develop, schedule and manage qualified technicians and engineers.

Effectively marketed company service capabilities increasing the number of accounts. Factory Mutual and Research, Norwood, MA 1982 to 1988 Resident Loss Prevention Consultant (Authorized Inspector, A.I.) Responsible for conducting loss prevention surveys as a resident engineer in Syracuse, New York, covering upstate New York and parts of New England. Surveys included the review of operational and maintenance procedures of mechanical and electrical equipment of various size industrial plants, including the jurisdictional certificate inspections (in-service and outage) of boilers and pressure vessels. Inspections included waterside and fireside evaluations incorporating various nondestructive examination techniques and issuance of Operating Certificates. Conducted operational and dismantled inspections on Steam and Gas Turbines monitoring electrical testing of generators. Graduate Studies 1979 to 1982 United States Lines, Inc. June 1980 to August 1980 Third Assistant Watch Engineer Employed during graduate school semester break by United States Line, Inc., as a Third Assistant Engineer aboard the container ship S.S. “American Lancer”. Three-month assignment to the Far East standing watch as operating engineer of main propulsion plant and auxiliary plant systems. Factory Mutual Engineering and Research, Norwood, MA 1977 to 1979 Boiler and Machinery Inspector/Loss Prevention Consultant (Authorized Inspector, A.I.) Assigned to the home office located in Norwood, MA, as a Boiler and Machinery Inspector, to conduct loss prevention surveys at various industrial facilities in New England. Also, responsible for conducting jurisdictional certificate inspections (in-service and outage) of boilers and pressure vessels. Inspections included waterside and fireside evaluations incorporating various nondestructive examination techniques and issuance of Operating Certificates.

EDUCATION

B.S. in Marine Engineering Massachusetts Maritime Academy, Buzzards Bay, MA

Graduate Coursework Saint John’s Seminary, College of Liberal Arts, Brighton, MA

PROFESSIONAL LICENSES

American Welding Society Certified Welding Inspector (CWI)

United States Coast Guard Third Assistant Engineering License Unlimited Horsepower Steam and Diesel

National Board of Boiler and Pressure Vessel Inspectors Commission

Inspectors’ License of Boilers and Pressure Vessels in the State of Connecticut, Maine, Massachusetts,

New Hampshire, New York, Rhode Island, and Vermont


Attachment Page 10

PROFESSIONAL DEVELOPMENT Theory and Application of Welding Inspection (ALSTOM Power Inc.)

Professional Trainer Certification as Instructor/Facilitator from Langevin Learning Services The Seven Habits of Highly Successful People (Covey Leadership Center)

GE Power Delivery & Control Seminar, (Presented by General Electric, Denver, CO) Industrial Fire Control Concepts Course (Presented by Industrial Risk Insurers)

Combustion and Steam Turbine Seminar (Presented by H. Parker & Company Inc., Bradenton, FL) Authorized Shop Inspectors Course (Presented by Factory Mutual)

Numerous seminars in topics such as:

Power Boilers, Pressure Vessels, Combustion Turbines, Steam Turbines, Hydraulic Turbines,

Nondestructive Examination , Compressors, Transformers, Electrical Distribution Systems, Motors, Generators, Bearings, Pumps, Fire Pumps, Sprinkler Systems and Design, Effective Writing, World Class

Maintenance, etc.


Attachment Page 11

RAYMOND L. MILETTI 1776 Bent Bow

Akron, Ohio 44313 330 - 801 - 6996

OBJECTIVE NBIC Main Committee assignment CAREER SUMMARY Thirty Two (32) years of experience working in various arenas of the Power Generation industry, serving in a management role for 22 years. Working knowledge of ISO, ASNT, API, AWS, ASME and NBIC quality programs / requirements.

PROFESSIONAL EXPERIENCE MANAGER, QUALITY OPERATIONS & SUPPLIER CONTROL – 02/16 – PRESENT BABCOCK & WILCOX - BARBERTON, OHIO

Manage the daily activities of 9 people that include Quality contract engineers and inspectors. In addition to the job assignments shown directly below, I have the added responsibility of the Supplier Control function for the company. Those duties include supplier evaluation/selection, inspection planning and quality cost evaluation.

MANAGER, QUALITY OPERATIONS – 07/10 – 02/16 BABCOCK & WILCOX CONSTRUCTION COMPANY – BARBERTON, OHIO Responsible for the planning and development of programs and processes that ensure company and customer quality requirements are met for BWCC business units. Manage and support projects from proposal stage through project completion, assuming responsibility for all quality related issues during project execution. Manage the supplier base from evaluation through order execution. Responsible for Quality program development and maintenance to assure compliance with ISO, ASME and NBIC, in addition to internal procedures and practices. Responsible for the management of renewal activities and provide clarification of Code requirements. Directs in the defining and implementation of training programs of field personnel in areas such as welding, heat treatment and NDE. MANAGER, QUALITY OPERATIONS & SUPPLIER CONTROL – 01/08 – 07/10 BABCOCK & WILCOX - BARBERTON, OHIO

Manage the daily activities of 10 people that include Quality contract engineers and inspectors. In addition to the job assignments shown directly below, I have the added responsibility of the Supplier Control function for the company. Those duties include supplier evaluation/selection, inspection planning and quality cost evaluation.

QUALITY OPERATIONS MANAGER 01/00 ---- 01/08 BABCOCK & WILCOX - BARBERTON, OHIO

Manage Quality Assurance engineers of various disciplines, responsible for the product quality across all product lines (traditional and non-traditional). Responsible for assuring the highest level of quality, using preventative, cost-effective measures. The position includes interface with both, customer and supplier quality organizations, in addition to auditing efforts in B&W manufacturing facilities. Scope of contract support includes the following: Support of proposal management with bid specification reviews, participation in proposal

meetings and development of quality proposal documents for submittal. Project execution support which includes quality (contract specific) plan development and

assuring satisfactory implementation. This may also include interface with erector.

Ray Miletti Resume 11-1-16Attachment

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Support of vendor control with preproduction meetings, surveillance and review/maintenance of QC documentation.

Additional work scope:

Maintenance of Quality Operations Manuals. Lead support for the off-shore suppliers. Support ISO-9001 program with internal auditing and assistance in certification surveillance

audits.

QUALITY CONTROL MANAGER - B&W SERVICE COMPANY 11/93 – 01/00 BABCOCK & WILCOX BARBERTON, OHIO Directly responsible for establishing cost-effective quality requirements for all products of the division, and ensure their effectiveness. Responsibilities included the following: Quality Manual coordinator responsible for maintaining accurate and current quality procedures support of B&W Foundry activity support of B&W warehouse (receipt inspection activity) supported Supply Management and Manufacturing in casting sublet effort (domestic and off-

shore) support of Supplier Control with surveillance activity and review of QC document submittals supported the off-shore machining effort in Korea and Taiwan support of Proposal Management with bid specification reviews and participation in proposal

meetings project support serving as QA Engineer for major projects which includes quality plan

development and implementation Also, served as lead auditor in performing internal ISO-9001 audits and assist during certification and surveillance ISO audits. QUALITY ASSURANCE ENGINEER 4/89 - 11/93 BABCOCK & WILCOX BARBERTON, OHIO Contract Quality Program Management, including interface with internal / external customers. Audit suitability/compliance with various control systems within B&W and sublet suppliers. Inspection of vendor supplied material and equipment. Proposal support - review bid specifications and preparation of preliminary fabrication / inspection plans. PROJECTS ENGINEER 1/85 – 4/89 SHARON MANUFACTURING SHARON CTR., OHIO Served as Project Engineer for structural steel fabricator. Responsibilities ranged from planning through completion of manufacturing. Interfacing with customers and vendors. Significant projects included the manufacturing of large steel molds used for manufacturing rubber sonar domes for the United States Navy (second tier supplier to the Navy).

EDUCATION BACHELOR OF SCIENCE IN CIVIL ENGINEERING 1984 THE UNIVERSITY OF AKRON AKRON, OHIO

PROFESSIONAL ACCOMPLISHMENTS

Earned Certified Welding Inspector (CWI) certification from the American Welding Society (August, 1993)

Member of the American Welding Society since 1993.


Attachment Page 13

NBIC Repair & Alterations Sub-Group since 2012

NBIC Repair & Alterations Sub-Committee since 2013


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Randal T. Cauthon

39 Gulf Road

Stafford Springs, CT 06076

(860) 830-0034

[email protected]

Education:

High School Graduate 1977

AWS CWI (Current) 2008

CEU Courses:

Purchasing and Inventory Management 1995

National Board Repair Organization 2011

ASME Section VIII, Div. 1 2012

ASME B31.1 2014

ASME B31.3 2014

ASME Practical Welding Technology 2016

Computer Literacy:

• Competent in Microsoft Windows: Microsoft Office, Access, Excel, Outlook,

PowerPoint, and Word

• Internet & email

• SAP

• Hardware configuration

• Networking

• Cellular Communications Systems

Work Experience:

GE Gas Power Systems as Lead Project Quality Specialist Nov. 2015 – Present

• Project Quality Lead

• Responsible for ASME Master Data Packages

• ASME resource

• AWS resource

• Primary contact for NBIC requirements

• Member NBIC Repairs and Alterations Subgroup Repairs and Alterations

• Mentor for new associates

• Primary contact for welding equipment questions

• Secondary contact for welding questions

• Nonconformance Management

• TapRoot Certified

• LRQA Certified ISO Auditor

• Oriel Stat A Matrix Certified Lead Auditor (117561)

• Responsible for ASME Code Manual revisions

Alstom Power Inc., HRSG as Project Quality Manager Sept. 2014 – Nov. 2015

• Project Quality Lead

• Responsible for ASME Master Data Packages

Randy Cauthon Resume 11-1-16Attachment

Attachment Page 15

• ASME resource

• AWS resource


• Member NBIC Repairs and Alterations Subgroup Repairs and Alterations



• Secondary contact for welding questions

• Nonconformance Management


• LRQA ISO:9001 Auditor

• Oriel Stat A Matrix Certified ISO:9001 Lead Auditor (117561)

• Alstom Lead Auditor

• ASME/NBIC Joint Review team lead in 2015

• Responsible for ASME Code Manual revisions

APComPower Inc. as Senior QA Engineer Feb. 2008 – Aug. 2014


• Member NBIC Repairs and Alterations Subgroup General and Repairs and Alterations

Subgroup Specific

• Competent Multi-tasker


• Time Management


• Weld Tracking Software Management

• Scaffold "Train the Trainer" Certified

• Jurisdictional License and Code compliance

• Nonconformance Management (Megasolve for Projects)


• LRQA ISO Auditor

• Alstom Lead Auditor

• 8D Leader

• SAFIR Level 4 Tester

• ASME/NBIC Joint Review team lead in 2009 and 2012

• Responsible for Code review of NBIC, ASME Section VIII, Div. 1, ASME Section I

(Quality), ASME B31.1 (Quality)

Activities:

• Safety Task Force 1991 – 1992

• Safety Steering Committee 1992 – 1995

• Safety Steering Committee (recurring presence) 2000 – 2007

• Quality Steering Committee 2009 – 2014

• Manufacturing & Materials Committee 2014 - 2016

Randy Cauthon Resume 11-1-16Attachment

Attachment Page 16

Experience Summary

PERSONAL DATA:

Name: Paul H. Schuelke Home: Address: 1587 N. Rustic Drive La Porte, IN 46350 Date of Birth: December 17, 1951 EDUCATION: 1983 Masters of Business Administration St. Ambrose University Davenport, Iowa 1974 Bachelor of Science in Mechanical Engineering South Dakota School of Mines and Technology Rapid City, South Dakota CERTIFICATIONS: California Professional Engineer Certificate No. M 18867 Six Sigma Black Belt TECHNICAL MEMBERSHIP: 1993 to 2013 Committee Member Currently an alternate The American Society of Mechanical Engineers Controls and Safety Devices for Automatically Fired Boilers 2013 to present National Board of Boiler and Pressure Vessel Inspectors Installation Code Part I subcommittee member Sub-group boiler & pressure vessel member EXPERIENCE: I have worked in the boiler industry for over 40 years, holding positions of salesman, consulting engineer and various engineering positions for boiler/burner manufactures. These include Manager Customer Engineering, Engineering Manager, Chief Engineer, Director

Paul Schuelke Resume 11-1-16Attachment

Attachment Page 17

Product Application, and Director Product Compliance. Currently I hold the position of Director, Technical Services for Weil-McLain. I am or have been responsible for pressure vessel design, boiler control system design, boiler and burner applications, service, and product compliance with ASME Section I, Section IV, CSD-AFB, Underwriters Laboratories, and other state and industry requirements.


Attachment Page 18

Paul H. Schuelke

1587 N. Rustic Drive

La Porte, IN 46350

EXPERIENCE: Jan 2006 to Director, Technical Services Present Weil-McLain 500 Blaine Street Michigan City, IN 46360 I have the responsibility to insure that products manufactured by Weil-McLain meet and

exceed customer expectations and industry standards. Specific areas of responsibilities are providing technical support for resolving insurance claims and product liability litigation. Also, I am the chairperson of the product safety design review committee.

Activities involved with resolving claims and litigation include working with attorneys,

coordinating experts, and participating in site investigations and product inspections for personal injury and property damage claims due to fires, explosions, water damage freeze damage, scalding, and construction accidents. Expert reports, affidavits, deposition and trail testimony are provided when needed.

The chair of the product safety design review committee oversees the activities of the

committee to verify that new products are designed and supplied to industry standard and installation instructions and warnings are suitable for the foreseeable use and misuse of the product. In addition, a Failure Mode Effect Analysis (FMEA) and appropriate follow-up action is completed on all items on the engineering bill-of-materials.

In addition, I oversee the Technical Service Technicians and Consumer Relations. These

groups answers boiler questions, heating system installation questions and operation questions, asked by the Weil-McLain sales force, distributors, contractors, engineers, and consumers.

Aug 1997 to Director, Product Compliance Jan 2006 Weil-McLain 500 Blaine Street Michigan City, IN 46360 I had the responsibility to insure that products manufactured by Weil-McLain meet and exceed

customer expectations and industry standards. Specific areas of responsibilities were providing technical support for resolving insurance claims and product liability litigation. Also, I was the chairperson of the product safety design review committee.

Activities involved with resolving claims and litigation include working with attorneys,

coordinating experts, and participating in site investigations and product inspections for personal injury and property damage claims due to fires, explosions, water damage freeze


Attachment Page 19

damage, scalding, and construction accidents. Expert reports, affidavits, deposition and trail testimony were provided when needed.

The chair of the product safety design review committee oversees the activities of the

committee to verify that new products are designed and supplied to industry standard and installation instructions and warnings are suitable for the foreseeable use and misuse of the product. In addition, a Failure Mode Effect Analysis (FMEA) and appropriate follow-up action is completed on all items on the engineering bill-of-materials.

Jan 1989 to Director, Product Applications Aug 1997 Weil-McLain 500 Blaine Street Michigan city, IN 46360 I was responsible for engineering and technical staff of eleven people who performed all

product application functions, provided technical field support, and wrote all technical publications including installation manuals. The Product Applications Department provided all job specific drawings, quotations and submittals for special boiler applications, answered all technical product and application questions from installers, distributors, consulting engineers, and sales personnel. All technical manual and service guides were developed and written by this group.

July 1987 to Engineer Jan 1989 Williams & Davis Boilers, Inc. P. O. Box AF Hutchins, TX 75141 I was responsible for all product engineering, product design, product drafting for a regional

boiler manufacturer with 5 to 7 million dollars of annual sales. They provided additional customer support preforming service, and boiler installations.

July 1984 to Chief Engineer July 1987 Stone Johnston Corporation 300 Pine Street Ferrysburg, MI 49409 I was responsible for the pressure vessel, mechanical and electrical design for fluidized bed

boiler systems, including fans, coal handling, limestone handling, natural gas delivery, control and instrumentation. Also, providing assistance to the Manager of Engineering in the day to day questions form manufacturing, sales, and management; the processing of standard boiler order; and providing support to the field sales force, Completed extensive research on CAD/CAM systems and the integration with the existing NC plasma-cutting equipment.

Mar 1984 to Manager of Engineering July 1984 Kewanee Boiler Corporation 101 Franklin Street


Attachment Page 20

Kewanee, IL 61443 I was responsible of all product engineering activities, including product design, order

processing, and research and development. Feb 1983 to Product and Sales Manager Mar 1984 Kewanee Boiler Corporation 210 W 22nd Street Oak Brook, IL 60521 I was responsible for the sale of firebox boilers, burners, waste heat boilers, and repair parts.

More than half of my time was spent at the plant in Kewanee, IL assisting the engineering department process sales orders. The reminder was spent on national market studies and sales support of the representative sales force.

Mar 1980 to Manager of Customer Engineering Feb 1983 Kewanee Boiler Corporation 101 Franklin Street Kewanee, IL 61443 I was responsible for the activities of 14 engineers and professional people who were engaged

in quotations, order entry, and boiler application engineering. This included pricing, terms and conditions of sales; order submittals preparation; compliance with Underwriters’ Laboratories; Factory Mutual; Industrial Rick Insurers; ASME section I and IV; and preparation of shop manufacturing drawings. In addition, I served as the technical contact for the sales force on boilers, boiler systems, burners, economizers and waste heat boilers. We implemented process systems to reduce the order processing time from 14 days to 4 days. Prepared the background studies on cost effectiveness of word processing and CAD systems, and over saw the design and the beginning of an in-house customer relations seminar.

May 1979 to Chief Engineer March 1980 Electric Boiler Corporation of America Subsidiary of Kewanee Boiler Corporation Atlantic, IA I was responsible for the design, research and development, quality control, service and

application for the electric boilers. The capacity ranged from 20 Kw to 1600 Kw and the pressure ranged from 15 psig to 1500 psig.

I was also responsible for the quality control of the guardian safety relief valve and the

Kewanee retrofit burner. In addition, I helped coordinate the burner field service with the Kewanee Boiler Corporation Field Service Manager.

I was the primary customer contact for all products. Sept 1978 to Mechanical Engineer May 1979


Attachment Page 21

Donald Bentley and Associates San Francisco, CA I was a boiler specialist and energy analyst working with a team of engineers on a 22 building

survey of the Lawrence Berkeley Laboratory. Primary responsibility was the detailing of existing mechanical systems and alternative system cost for a DOE 1 computer analysis. In addition, I was the primary writer of the mechanical reports and assistant editor of the project.

Jan 1975 to Engineering Sales Sept 1978 L. O. Schuelke Company, Inc. San Carlos, CA 94070 I worked with purchasing agents, engineers, contractors and maintenance personnel in

Northern California on the selection and operation of industrial boilers, burners, and heat exchangers. I was responsible for the sales, coordinating shipments, original start-up, warranty and emergency service.

May 1974 to Summer Laboratory Assistant Sept 1974 Kewanee Boiler Corporation Kewanee, IL 61443 Assisted in the research and development of burners, also, conducted Environmental

Protection Agency Tests on boiler stack emissions, and addicted in various other experiments in the laboratory.

May 1973 to Summer Office Engineer Sept 1973 L. O. Schuelke Company, Inc. San Carlos, CA 94070 I was responsible for the selection and sales for American Standard shell and tube heat

exchangers. This was done by working with factory personnel to provide economical selections to the customer.

1970 to Part time and summer employment. 1972 Christian Candles, Inc. Redwood City, CA I was responsible for general maintenance and construction at the factory.

EDUCATION: 1983 Masters of Business Administration St. Ambrose University Davenport, IA


Attachment Page 22

1974 Bachelor of Science in Mechanical Engineering South Dakota School of Mines and Technology Rapid City, SD Organizations: Theta Tau Fraternity Wrestling Team American Society of Mechanical Engineers Student 1970 San Carlos High School San Carlos, CA

CERTIFICATION: California Professional Engineer Certificate Number M 18867 Six Sigma Black Belt

TECHNICAL MEMBERSHIPS: 1993 to Committee Member Present The American Society of Mechanical Engineers Controls & Safety Devices for Automatically Fired Boilers

SEMINARS: DRI Product Liability NAFI – Fire and Explosion Cause and Origin

HOBBIES: Hunting, fishing, scuba diving, photography, and R/C model airplanes.

PERSONAL: Date of Birth: December 17, 1951 Height: 5’-11” Weight: 180 lbs. Health: Excellent Married with 3 children


Attachment Page 23

Darrell Graf

100 Bass Rd Carriere, Ms. 39426

Objective Become a member of the subcommittee on inspections

Become a member of the NBIC Main Committee

Professional Achievements NBIC In-Service Inspector NB# 14685

Current member of the subgroup inspection

Skills

Develop mechanical integrity programs for the plants within Air Products. Use an in house developed Risk Based Inspection program to develop and maintain MI programs for Hydrogen plants, air separation plants, Cogen plants, high purity N2 / O2 plants and liquid bulk distribution systems.

Knowledgeable in API 510 Pressure Vessels Inspection Code

Knowledgeable in API 570 Piping Inspection Code

Knowledgeable in API 571 damage mechanisms

Knowledgeable in API 579 Fitness for Service

Knowledgeable in API 580 Risked Based Inspection

NACE Basic Corrosion

ASME Boiler and Pressure Vessel repair and inspection

Work with inspection companies to qualify the technicians for work in the Air Products plants, understand the various NDE techniques and how they best fit the unique challenges the gasses industries face.

Work History

Principal Mechanical Integrity Technician

Air Products & Chemicals Inc.

Allentown, Pa. 18195-1801

08/01/1983 – Present

Plant operations 08/01/1983 – December 1995

Process Safety Technician Coordinator Jan 1996 thru June 1998

Senior Mechanical Integrity Technician June 1998 thru Dec 2013

Darrell Graf Resume 11-1-16Attachment

Attachment Page 24

Principal Mechanical Integrity Technician 2013 thru present

\References

Chad Texter Global Mechanical Integrity Manager Air Products & Chemicals Inc.

Darrell Graf Resume 11-1-16Attachment

Attachment Page 25

8944 RIVERWOOD DRIVE NORTH RIDGEVILLE, OH 44039 M: 216.804.1183 EMAIL: [email protected]

Page 1

JASON M. SAFARZ

EXPERIENCE HIMA Americas, Inc. November 2016 - Present Regional Sales Manager

Regional sales manager for safety solutions in industrial automation, burner management systems, and emergency shutdown systems. Specializing in SIL3 rated safety PLC based systems for fired equipment and high hazard industries.

Honeywell HTS (Honeywell Thermal Solutions) January 2016 - October 2016 Sr. Sales Engineer Acquired by Honeywell (January 2016)

Global accounts managment and sales for strategic end users in the automotive, building materials, and pharmaceutical segments.

CEC Combustion Safety, an Eclipse Company October 2011 - December 2015 Sr. Account Engineer, Sales & Marketing Manager Acquired by Eclipse (August 2011) then Elster Thermal Solutions starting (October 2014)

Key account sales and account management for safety services, system upgrades, and training. Development of global corporate programs. Directing sales and marketing activities for CEC Combustion Safety, synergy sales with Eclipse sales teams globally, and increasing incremental sales of Eclipse and partner products. Increased sales by 44% between CY2011 and CY2014 while improving margin.

CEC Combustion Safety, LLC March 1999 - October 2011

Field Service / Mechanical Engineer, Account Engineer CEC Consultants, Inc. June 1995 - February 1999 Engineering Assistant, AutoCAD Drafter, Project Manager EDUCATION CLEVELAND STATE UNIVERSITY: B.S.M.E. May 1999 BALDWIN WALLACE COLLEGE: B.A. (Physics) May 1999

Sigma Phi Epsilon Fraternity, Ohio Zeta Varsity Soccer

Jason Safarz Resume 11-10-16Attachment

Attachment Page 26

mailto:[email protected]


Page 2

QUALIFICATIONS SALES & SALES MANAGEMENT Increased business over a recent three year period in bookings by 44% over set goals while increasing Return on Sales (RoS)/EBIT and achieved nearly a 70% close ratio. Continually exceeded sales goals for team and individuals using management by exception process. Assisted in development of a global accounts team within Eclipse including interfacing with local territory sales personnel and independent representatives (Agents). Averaged one new large global client per year with an average revenue of approximately $1.0 million each. Created pricing templates and specific selling tools for our business units. Member of global team determining pricing and cost modeling of all Eclipse and CEC Combustion Safety products. Generated detailed proposals for engineering studies, safety inspections, design jobs, training, and equipment upgrades. Maintained and exceeded minimum profit margin expectations. Sales Methodology

Global selection team member for CRM and sales methodology with Eclipse. Lead development and adoption team for Eclipse Global sales staff (approximately 100 sales

personal and managers) in Americas, Europe, and Asia. Created and executed materials and templates for use by all sales teams. Developed and

executed a rollout plan to stage in process over a 12-18 month period. Customized CRM to overlay terminology and sales process.

Client Relationship Management (CRM)

Implemented SalesForce.com for company use, then later WinMan CRM including data mapping, development of customized formats and reporting, pipeline analysis, and forecasting.

Campaign tracking for all major marketing and sales efforts including return on sales for trade-shows, eBlasts, white papers and presentations, and open training courses.

BUSINESS MANAGEMENT Developed audit process for combustion systems and implemented this process for many global Fortune 500 corporations worldwide. Includes development of current employers training standards for new employees. Created new business plans and annual strategies for establishment of company product and future growth. Revised approach and execution for business plan as company grew into new areas. Maintain high level relationships with insurance, risk managment, and broker industry. Top relationships are with Zurich, AXA Matrix, GRC, FM Global, XL, Marsh, AON, and Chubb. Directed every stage of a project: opportunity development, estimating, proposal, design and implementation, installation, training, invoicing, and final follow-up for success criteria. Facilitate problem-solving meetings to generate creative solutions with new and existing clients. Evaluated new combustion system technologies and cross applications of related European (EN) codes.


Attachment Page 27



Page 3

TRAINING/PRESENTING Designed and implemented training curriculum for workshops on combustion system fundamentals/operations, boilers, process equipment and related standards and codes. Developed customized presentations to specific needs of an audience, company or organization and presented these to groups of 10 to 300 worldwide. Created hands-on activities and manipulatives to illustrate key concepts in the curriculum. Experience in writing papers for trade associations and delivering associated presentations and webinars. Presentations include to associations such as ABMA, ASME, RIMS, SFPE, SMRP, SEMPES, and several insurance/risk management carriers. ENGINEERING Fluent in many computer applications including Microsoft Office (Word, Excel, Access, PowerPoint, Project), RsLogix, AutoCAD, Refrigerant Compliance Manager, WebEx, WinMan ERP, SalesForce (CRM), and Landslide (CRM). Analyzed all varieties of combustion systems for proper and safe operation and code compliance. Root Cause and Fault Tree Analysis for problematic systems, near miss incidents, and explosions. Occupational Hazard Assessments (OHA) for at risk combustion systems. Provided energy audits for large industrial and commercial clients. Projects included lighting retrofits, point of use heating projects, waste minimization, water reclamation, combustion equipment efficiency tuning, lead-lag boiler operation, and compressed air leak minimization and optimization. Developed bid specifications for major power plant upgrades including boiler controls, PLC control upgrades, and water system retrofits. COMMITTEE MEMBERSHIP & PROFESSIONAL DEVELOPMENT AMERICAN SOCIETY OF MECHANICAL ENGINEERS Member, September, 1997-Present

ASME CSD-1 (Controls and Safety Devices for Automatically Fired Boilers) Committee Member, May 2003 - Present Committee Chairman April 2013 through 2019 (two consecutive terms)

Attend biannual meetings to discuss code revision. Chaired project teams that researched the impact of changes to the standard and proposed new revisions. Joint task group for aligning equivalent codes and standards including international standards. As chairman of committee prepared meeting agendas and minutes, reported to ASME staff on activites, ran two day meetings biannually.

NATIONAL BOARD OF BOILER AND PRESSURE VESSEL INSPECTORS National Board Inspection Code (NB-23) Part 2: Inspections, Member


Attachment Page 28



Page 4

UNDERWRITERS LABORATORY UL 834 Standard Technical Panel for Heating, Water Supply, Power Boilers - Electric SANDLER SELLING & SALES MANAGEMENT SOLUTION SELLING (Sales Performance International) Solution Selling Team Presentation Award, Europe October 2013 OTHER TRAINING/MEMBERSHIPS

CEC Combustion Safety, Inc. - Junior & Senior Auditor Course Allen-Bradley Fundamentals of Programmable Controller Systems Eclipse Combustion Seminar Maxon Burner & Valve Seminar North American Combustion Courses OSHA Approved Course General Industrial Safety CPR Certified ITT Engineers Training for Pumps and Hydronic Systems Universal Refrigeration License, #071505022075 www.safe2work.com compliance Nalco water treatment courses Association of Energy Engineers (AEE), Past Member Risk Insurance Management Society (RIMS), Member Society of Maintenance and Reliability Professionals (SMRP), Member Market Driven Organic Growth - Kellogg School of Business Global Entry for International Travel (TSSA) International Society of Automation (ISA), Member


Attachment Page 29


http://www.safe2work.com/

NB-240, Proposed Rev. 15 Page 1 of 21

National Board Inspection Code Procedure

Approved by NBIC Committee: Approved by the Board of Trustees: Approved by ANSI:

The National Board of Boiler & Pressure Vessel Inspectors

1055 Crupper Avenue Columbus, OH 43229-1183

Phone: (614)888-8320

NB-240 Proposed Rev. 15 11-18-16Attachment

Attachment Page 30


Table of Contents 1.0 Purpose ....................................................................................................................................... 3

2.0 Responsibilities ........................................................................................................................... 3

3.0 Definitions .................................................................................................................................. 3

4.0 Committee Structure ................................................................................................................... 4

4.1 NBIC Committee ............................................................................................................................ 4

4.2 Subcommittees ............................................................................................................................... 6

4.3 Subgroups ....................................................................................................................................... 7

4.4 Task Groups ................................................................................................................................... 9

4.5 Interest Categories .......................................................................................................................... 9

5.0 Duties of NBIC Committee, Subcommittee, Subgroup and Task Group Membership ............ 10

5.1 Chair ............................................................................................................................................. 10

5.2 Vice Chair..................................................................................................................................... 11

5.3 Secretary ....................................................................................................................................... 11

5.4 Members ....................................................................................................................................... 11

6.0 Meetings ................................................................................................................................... 11

6.1 Scheduled Meetings ..................................................................................................................... 11

6.2 Locations ...................................................................................................................................... 11

6.3 Meeting Notification .................................................................................................................... 11

6.4 Public Meetings ............................................................................................................................ 12

6.5 Quorum ......................................................................................................................................... 12

6.6 Meeting Conduct .......................................................................................................................... 12

6.8 Minutes ......................................................................................................................................... 12

7.0 Voting ....................................................................................................................................... 13

7.1 General ......................................................................................................................................... 13

7.2 Voting at Meetings ....................................................................................................................... 14

7.3 Voting by Letter Ballot ................................................................................................................. 14

7.4 Final Approval Vote ..................................................................................................................... 15

8.0 National Board Inspection Code Publication Information ....................................................... 15

8.1 ANSI Approval Process ............................................................................................................... 15

8.2 Revisions to the NBIC .................................................................................................................. 17

8.3 Interpretations of the NBIC .......................................................................................................... 18

8.4 Publications .................................................................................................................................. 19

8.5 General ......................................................................................................................................... 19

9.0 Due Process .............................................................................................................................. 19

10.0 Records ..................................................................................................................................... 20

11.0 Antitrust Policy ......................................................................................................................... 21


Attachment Page 31


1.0 Purpose This procedure defines the organization, scope, duties and responsibilities of the NBIC Committee, subcommittees, subgroups and task groups. The NBIC Committee is established by the National Board of Boiler and Pressure Vessel Inspectors (NBBPVI) Board of Trustees for the purpose of maintaining the NBIC. NBBPVI is accredited by ANSI as a “developer of American National Standards” in accordance with the ANSI Essential Requirements. This procedure also describes the administrative process for the publication of the National Board Inspection Code. Revisions to this procedure must be approved by the NBIC Committee, the Board of Trustees, and ANSI. A copy of this procedure or any referenced document is either available on the National Board’s Web site: www.nationalboard.org or may be obtained from the NBIC secretary.

2.0 Responsibilities

The Executive Director of the National Board is responsible for ensuring that the requirements of this procedure are met. The Secretary of the NBIC Committee is responsible for the day-to-day implementation of this procedure. Other responsibilities are described throughout this procedure.

3.0 Definitions

The following are terms and their definitions used throughout this document. ANSI American National Standards Institute

Board The Board of Trustees of the National Board

Code The National Board Inspection Code (NBIC)

committee The NBIC Committee and all subcommittees, subgroups and

task groups

NBIC Committee The NBIC Main Committee is the final consensus body for the purpose of approving American National Standards

National Board The National Board of Boiler and Pressure Vessel Inspectors (NBBPVI) is the ANSI-Accredited Standards Developer

NBIC The National Board Inspection Code which was established to

provide rules and guidelines for the repair, alteration, inspection, installation, maintenance and testing of boilers,


Attachment Page 32


pressure vessels and other pressure retaining items.

project manager Individual assigned the responsibility for developing, monitoring and responding to technical items.

subcommittee A unit established to address recurring functions, address specific issues or maintain specific sections of the NBIC. A subcommittee is established by the NBIC Committee. Each subcommittee will follow rules for consensus approval insofar as possible but is not considered the final consensus body for the purpose of approving American National Standards.

subgroup A unit established to address recurring topics or functions specific to a subcommittee. A subgroup is established by the NBIC Committee. Subgroup actions are reported to the subcommittee for approval.

task group A unit established to address a specific topic. A task group may be established by the NBIC Committee, subcommittee or subgroup.

4.0 Committee Structure

The committee structure consists of the NBIC Committee, subcommittees, and subgroups appointed by the NBIC Committee and task groups appointed by the NBIC Committee, a subcommittee or subgroup. The duties, responsibilities and administration of each are described below.

4.1 NBIC Committee

4.1.1 Responsibilities

The NBIC Committee is responsible for:

a. approving new rules and revising existing rules of the Code and voting

on such additions and revisions;

b. approving interpretations of the rules of the Code;

c. hearing requests for reconsideration regarding interpretations and revisions to the Code;

d. acting on any matter related to the scope of the Code as may be assigned by the Board.

4.1.2 Membership


Attachment Page 33


The NBIC Committee shall consist of not more than twenty-six (26) voting members within the interest categories described in paragraph 4.5.

a. At least one individual representing manufacturers shall be employed by

a manufacturer of safety relief devices.

b. At least one individual representing National Board Certificate Holders shall be employed by an organization holding a valid “R” Certificate of Authorization.

c. At least one individual representing National Board Certificate Holders shall be employed by an organization holding a valid “VR” Certificate of Authorization.

d. Not more than one-third of the total NBIC Committee membership shall represent any single category of interest. The chair and vice chair of the NBIC Committee are considered within this membership. The secretary is a member of the NBIC Committee without vote.

e. Each member of the NBIC Committee may recommend a person, within the same interest category, as a representative to serve in the absence of the member at a specific meeting. Representatives have the same privileges and responsibilities as the member when serving in the member’s capacity. The representative’s involvement terminates at the conclusion of the specific meeting requested by the member.

f. Upon change of employment status affecting the member’s category of interest, NBIC Committee members shall notify the NBIC Committee secretary and will be deemed to have submitted their resignations from the NBIC Committee. Reappointment to the NBIC Committee shall follow the requirements of paragraph 4.1.3.

4.1.3 NBIC Committee Member Selection, Approval, and Term

a. A candidate for appointment or reappointment as a voting member of the

NBIC Committee is selected by a majority vote of the NBIC Committee membership. The candidate’s name is then submitted to the Chairman of the Board for consideration. All voting members of the NBIC Committee must be appointed by the Chairman of the Board.

b. A candidate for appointment or reappointment as the NBIC Committee Chair or Vice Chair is selected by a majority vote of the NBIC Committee membership. The candidate’s name is then submitted to the Chairman of the Board for consideration. The chair and vice chair must be appointed by the Chairman of the Board.


Attachment Page 34


c. The NBIC Committee secretary is selected by the Executive Director of

the National Board and is considered to be a non-voting member of the NBIC Committee without any interest affiliation.

d. The term of all voting members is three (3) years. Voting members are eligible for reappointment.

e. The term for the chair and vice chair is the same as their NBIC Committee membership expiration date. The chair and vice chair are eligible for one renewal of their terms of office, or two renewals if the duration of their first term was less than one year.

f. A candidate for membership on the NBIC Committee must provide a work history/resume to the NBIC Committee secretary.

4.2 Subcommittees


Subcommittees are responsible for:

a. maintaining (adding new requirements, revising existing requirements)

those sections of the NBIC that are assigned to the subcommittee.

b. acting on requests for interpretations of the rules for those assigned sections of the NBIC;

c. acting on any matter related to the scope of the NBICas may be assigned by the NBIC Committee;

d. forwarding all subcommittee actions to the NBIC Committee.

4.2.2 Membership

a. The number of members appointed to each subcommittee shall be as necessary to carry on the assigned responsibility. The size of subcommittees will be limited to numbers which will best serve operational needs.

b. Each member of the NBIC subcommittee may recommend a person, within the same interest category, as a representative to serve in the absence of the member at a specific meeting. Representatives shall have the same privileges and responsibilities as the member when serving in the member’s capacity. The representative’s involvement automatically


Attachment Page 35


terminates at the conclusion of the specific meeting requested by the member.

c. Upon change of employment status affecting the member’s category of interest, NBIC Subcommittee members shall notify the NBIC Committee secretary and will be deemed to have submitted their resignations from the subcommittee. Reappointment to the NBIC Subcommittee shall follow the requirements of paragraph 4.2.3.

4.2.3 Subcommittee Member Selection, Approval and Term

a. A candidate for appointment or reappointment as a voting member of the

subcommittee is selected by majority vote of the NBIC Committee membership. Subcommittee members need not necessarily be members of the NBIC Committee or subgroup. The candidate’s name is then submitted to the Chairman of the Board for consideration. All voting members of the subcommittee must be appointed by the Chairman of the Board.

b. Candidates for appointment or reappointment as the subcommittee chair and vice chair are selected by a majority vote of the subcommittee membership. The candidate’s names are then submitted to the Chairman of the Board for consideration. The chair and vice chair must be appointed by the Chairman of the Board.

c. The subcommittee secretary is a member of the subcommittee without vote and is selected by the Executive Director of the National Board.

d. The term for all voting members is three (3) years. Voting members are eligible for reappointment.

e. The term for the chair and vice chair is the same as their subcommittee membership expiration date. The chair and vice chair are eligible for one renewal of their terms of office, or two renewals if the duration of their first term was less than one year.

f. A candidate for membership on the subcommittee must provide a work history/resume to the NBIC Committee secretary.

4.3 Subgroups


Subgroups are responsible for:


Attachment Page 36


a. developing new rules and revising existing rules for specific Code sections or paragraphs;

b. acting on requests for interpretations of the rules for specific Code sections or paragraphs;

c. acting on any matter related to the scope of the Code as may be assigned by the committee or subcommittee;

d. forwarding all subgroup actions to the subcommittee, as appropriate

4.3.2 Membership

The number of members appointed to each subgroup shall be as necessary to carry out the assigned work. The size of subgroups will be limited to numbers to best serve operational needs.

4.3.3 Subgroup Member Selection, Approval and Term

a. A candidate for appointment or reappointment as a member of the

subgroup is selected by the majority vote of the subcommittee membership. Subgroup members need not necessarily be members of the Committee or subcommittee. The candidate’s name is then submitted to the Chairman of the Board for consideration. All voting members of the subgroup must be appointed by the Chairman of the Board.

b. Candidates for appointment or reappointment as subgroup chair and vice chair are selected by a majority vote of the subcommittee membership. The chair and vice chair of each subgroup shall be appointed by the Chairman of the Board.

c. The subgroup secretary is selected by the Executive Director of the National Board and is a member of the subgroup without vote. In the absence of a selected secretary, the subgroup chair may appoint a voting member of the subgroup to act as secretary.

d. The term for all voting members is for three years. Voting members are eligible for reappointment.

e. The term for the chair or vice chair is the same as their membership expiration date and these positions are eligible for one renewal., or two renewals if the duration of their first term was less than one year.

f. The name of a National Board Member who is a candidate to serve on a subgroup, but is not a member of the NBIC Committee or a


Attachment Page 37


subcommittee, must be submitted to the Chairman of the Board for approval.

g. A candidate for membership on a subgroup must provide a work history/resume to the NBIC Committee secretary.

4.4 Task Groups


Task groups are responsible for:

a. developing new rules and revising existing rules for specific Code topics

or paragraphs;

b. acting on requests for interpretations of the rules for specific Code topics or paragraphs;

c. acting on any matter related to the scope of the Code as may be assigned by committees;

d. forwarding all task group actions to the committee as appropriate.

4.4.2 Membership

The number of members appointed to each task group shall be as necessary to carry out the assigned task. The size of task groups will be limited to numbers which will best serve operational needs.

4.4.3 Task Group Members Selection, Approval, and Term

a. When the committee agrees on the need or at the discretion of the chair

of a committee, a task group, members, and chair shall be appointed by the committee chair. A member of the task group may be appointed as task group secretary by the task group chair. Task group members need not necessarily be members of a committee.

b. The name of a National Board Member who is a candidate to serve on a

task group, but is not a member of the NBIC Committee or a subcommittee, must be submitted to the Chairman of the Board for approval.

c. The task group will be dismissed once the task has been completed or at

the discretion of the chair of the committee.

4.5 Interest Categories


Attachment Page 38


NBIC Committee, subcommittee, subgroup and task group members shall not be considered as representing any specific organization. Participation by individuals employed by governmental agencies or affiliated with industry is not to be interpreted as government or industry endorsement. Membership shall be selected from the categories of interest listed below.

a. General Interest: Individuals who are not employed by an organization

characterized by b through h shall be considered General Interest.

b. Manufacturers: Any organization accredited by ASME to hold an ASME Code symbol stamp.

c. Authorized Inspection Agency: An authorized (insurance) inspection agency recognized by the National Board.

d. Jurisdictional Authorities: National Board members.

e. National Board Certificate Holders: Repair organizations accredited by the National Board to hold “R”, “NR” or “VR” certification.

f. Users: Owners or users of boilers/pressure vessels.

g. Labor: Individuals representing labor organizations whose members are skilled workers in boiler or pressure vessel manufacturing or repairing, such as the United Association of Journeymen and Apprentices of Plumbing and Pipe Fitting Industry of the United States and Canada or the International Brotherhood of Boilermakers, Ship Builders, Blacksmiths, Forgers and Helpers.

h. Regulatory Authorities: Representatives of US Governmental agencies that regulate boilers or pressure vessels or both.

Lack of any particular representative of any interest category at a meeting shall not preclude the committee from conducting its business when a quorum is present.

5.0 Duties of NBIC Committee, Subcommittee, Subgroup and Task Group Membership

5.1 Chair

The chair shall preside at meetings of the committee and shall perform other duties as are customarily assigned to that position.

The chair of the NBIC Committee shall make an annual review of the activity of each voting member of the NBIC Committee, subcommittee and subgroup with regard to the member’s contribution to the work, attention to correspondence, and


Attachment Page 39


attendance at meetings. Based on this review, if a consistent lack of attendance or participation within the past year is noted, the chair may recommend to the Chairman of the Board that the member’s appointment to the NBIC Committee be terminated. The chair’s report of NBIC Committee member’s activities shall be sent to the Chairman of the Board and the Executive Director of the National Board.

5.2 Vice Chair

The vice chair shall, in the absence of the chair, fulfill the duties of the chair.

5.3 Secretary

In addition to the responsibilities required by this procedure, the Secretary shall prepare agendas and record minutes of meetings and shall perform such other duties as are customarily assigned to such an office. In the absence of the chair and vice chair at a meeting, the secretary shall take the chair for the purpose of receiving nominations from the members present for election of a chair pro tem, who shall then preside at the meeting.

5.4 Members

The duty of each member is to give thorough consideration to each subject brought before the committee for action, vote on acceptance or rejection of each proposal, and assist generally in carrying out the assigned functions. Such duties may be carried out by attendance at meetings, by correspondence, and by telephone.

6.0 Meetings

6.1 Scheduled Meetings

NBIC Committee meetings shall be held at the call of the Chair, as decided upon by a majority of NBIC Committee members, or as directed by the Chairman of the Board. Subcommittee, subgroup and task group meetings held at times and locations other than in conjunction with the NBIC Committee meeting shall require the approval of the National Board Executive Director. Meeting requests shall be in writing to the Executive Director and include the subcommittee, subgroup or task group members’ roster.

6.2 Locations

The NBIC Committee shall meet in National Board member jurisdictions.

6.3 Meeting Notification


Attachment Page 40


All committee meeting schedules shall be posted on the National Board web site. The National Board member in whose jurisdiction the NBIC Committee is meeting shall be invited to attend the meeting. A meeting agenda shall be made available to the members prior to the meeting and shall be subject to approval at the commencement of each meeting.

6.4 Public Meetings

Meetings at which the committee considers proposed revisions to the NBIC, reaffirmation of previously considered revisions or withdrawal of previously approved revisions shall be open to the general public. Unless matters to be discussed by the committee are deemed to be of a confidential nature by the chair, committee meetings shall be open to any interested person who shall be given an opportunity to participate in the discussions on subjects of interest to them.

6.5 Quorum

Fifty-one percent of the NBIC Committee, subcommittee or subgroup voting membership eligible to vote must be present to conduct committee business.

6.6 Meeting Conduct

The committee shall conduct meetings in accordance with the latest available edition of Roberts Rules of Order (Revised) unless rules to the contrary are specified in these procedures.

6.7 Recording Meeting Proceedings

Taping of committee meetings, other than by the secretary, is prohibited.

6.8 Minutes

All meetings of the NBIC Committee, subcommittees and subgroups shall be documented in minutes of the meeting. The minutes are not to be considered a verbatim record of the meeting but rather a record of the voted actions and highlights of significant discussions or conclusions. The title page of committee minutes shall include the following statements:

“These minutes are subject to approval and are for committee use only. They are not to be duplicated or quoted for other than committee use.”

Minutes of committee meetings will be distributed to the members of the committees, the Executive Director, National Board members and Advisory Committee members, as requested. Copies of committee minutes will be made


Attachment Page 41


available on the National Board’s Web site for review until the next scheduled meeting minutes are available.

7.0 Voting

7.1 General

7.1.1 Each committee member shall exercise their vote within the presented time limits. When a committee member fails to report when due, or consistently abstains from voting, the committee member’s appointment shall be subject to termination. The individual may appeal such action. Committee members are encouraged to vote as soon as possible.

7.1.2 Votes for committee actions may be obtained by letter, fax, recorded votes at

meetings, or electronic means. All committee members shall have an opportunity to vote. When recorded votes are taken at meetings, the committee members who are absent shall be given the opportunity to vote.

7.1.3 The vote of each committee member shall be in one of the following

categories:

Approved Disapproved Abstention Not voting (for possible conflict of interest)

A response of not voting signifies neither approval nor disapproval and should be executed only when the committee member believes that they have a conflict of interest or potential conflict of interest and is removing themselves from the voting process. Committee members casting disapproved responses should include an alternate action that will resolve their disapproved vote. Committee members casting abstained responses should include a reason for the abstention.

7.1.4 Approval of committee actions shall be by a majority vote. Approval of the

following actions of the NBIC Committee or subcommittee shall require two-thirds (2/3) majority vote of the committee membership, excluding not voting responses:

committee procedures and interest categories reaffirmation of the NBIC as an ANSI Standard NBIC revisions interpretation of the NBIC


Attachment Page 42


scope of the NBIC Committee or subcommittee New ANSI standard

7.1.5 Voting by NBIC Committee members not present at a meeting or by letter

ballot may be obtained by letter, facsimile, or by other electronic means.

7.2 Voting at Meetings

NBIC Committee members not present at a meeting for final approval of Code revisions shall be afforded the opportunity to submit their vote within two weeks after the date of the NBIC Committee meeting. It is the responsibility of the National Board to provide the information relating to the items prior to the meeting in the form of posted Agendas. Disapproved actions at the meeting shall be placed on the Subcommittee agenda for the next scheduled meeting.

7.3 Voting by Letter Ballot

7.3.1 A letter ballot on any subject requires a response of at least fifty-one percent

of committee members eligible to vote and may be authorized by the Chair of the NBIC Committee, Chair of a subcommittee, Chairman of the Board, or a majority vote of those present and voting at a NBIC Committee or subcommittee meeting. The voting period for a letter ballot may be four (4) calendar weeks; however, in order to expedite the item, this period may be shortened to no less than two calendar weeks by the person authorizing the letter ballot. Voting periods shall be closed upon receipt of all responses, but not later than the established closing date. All letter ballots shall be coordinated by the NBIC Committee secretary.

7.3.2 At the conclusion of the letter ballot period, the NBIC Committee or

subcommittee secretary shall tally the votes and report the results to the members. If the letter ballot is disapproved, the item shall be placed on the agenda for the next meeting. All comments may be reviewed electronically by the NBIC Committee members or subcommittee members during the letter ballot period. The Project Manager shall respond in writing to all negative comments received. The response shall include a disposition to the comment, and reasons for that disposition. If a comment is submitted that does not pertain to the ballot under consideration, the comment shall be reviewed as a new revision request to the code. Upon Project Manager responses to negative comments, the letter ballot (with or without substantive revisions) and attempts at resolution shall be resubmitted for a two week time period for members to respond, reaffirm or change their original vote. Reaffirmation does not require a response during this voting period. At the conclusion of the letter ballot period, the NBIC Committee or subcommittee secretary shall tally the votes and report the results to the members. The Project Manager


Attachment Page 43


shall communicate with negative commenters in order to resolve their concerns, whenever possible.

If the required vote approval percentage is affirmative after this time period, the ballot shall be considered approved. Letter ballots not approved shall be placed on the agenda for the next scheduled meeting of the NBIC Committee or subcommittee.

7.4 Final Approval Vote

Prior to publication of a new edition of the NBIC, all substantive changes to the NBIC that have been approved by the NBIC Committee shall be gathered in a final draft standard document. A vote shall be taken by the NBIC Committee to approve the final draft standard document as the new edition of the NBIC. This vote serves as the final approval for all revisions to the NBIC. No substantive changes shall be made to the approved final draft standard unless the final draft standard is recirculated to the NBIC Committee in order to afford all members the opportunity to respond, reaffirm, or change their vote. The draft standard shall be submitted for an additional public review period if substantive changes are made to the document. If an NBIC Committee member votes ‘Disapproved’ on the final vote, that member shall submit reasons for the ‘Disapproved’ vote in writing to the NBIC Secretary. The NBIC Secretary may communicate with the member to resolve their negative vote. If the member remains unresolved in their objection, the ballot and attempts at resolution of the negative shall be resubmitted for a two week time period for members to respond, reaffirm or change their original vote. If the member remains unresolved with their ‘Disapprove’ vote after the two week reaffirmation period, the member shall be notified in writing of their right to appeal the final committee decision.

8.0 National Board Inspection Code Publication Information

8.1 ANSI Approval Process

NBBPVI is accredited by ANSI as a developer of American National Standards. The NBIC Committee, subcommittees, subgroups and task groups must conduct activities in accordance with this procedure and the current rules and procedures of ANSI.

8.1.1 Documentation

a. After the NBIC Committee has approved the draft standard, the secretary

shall prepare and submit a Standards Action Public Review Request (BSR-8) form. A notice of all revisions shall be posted on the National Board’s Web site for public review and comment. This notice shall be


Attachment Page 44


posted for a minimum of forty five days, or a minimum of sixty days if requested by an interested party.

b. The secretary shall coordinate the disposition of public review comments with the Project Manager.

c. The disposition of all public review comments shall be approved by the NBIC Committee.

d. The commenter shall be advised, in writing, of the disposition of the public review comment and the reasons for the disposition. The commenter shall be notified of their right to appeal the NBIC Committee’s decision.

e. All NBIC Committee members shall be notified of all unresolved public review comments and attempts at resolution to afford all members an opportunity to respond, reaffirm or change their vote. Any commenter with unresolved comments shall be notified in writing of their right to appeal.

f. Resolutions involving substantive changes to approved text shall be resubmitted for public review at the next scheduled public review and comment period or a new action shall be generated to address the commentators recommended change as appropriate.

g. When the disposition of all comments has been completed, or if no comments were submitted, the secretary shall prepare and submit the Formal Submittal Checklist for approval or withdrawal as an American National Standard (BSR-9) Form.

8.1.2 Secretariat

a. The National Board is the secretariat for the NBIC Committee. Its duties

include:

1. providing administrative support for the activities of the secretary, and

2. publishing and distributing the Code, minutes and interpretations approved in accordance with these procedures.

b. It shall be the responsibility of the secretary to:

1. ensure that the NBIC Committee adheres to these and other

referenced or applicable procedures, 2. apply to ANSI for accreditation of the NBIC Committee by that

organization,


Attachment Page 45


3. maintain a committee roster of the members which shall include names of the officers, and members, their address, business affiliation, category of interest, appointment expiration date,

4. comply with ANSI requirements for the NBIC Committee administration, and

5. submit proposed revisions to this procedure to ANSI for approval.

8.1.3 Internal Audits

At least once every three calendar years, the Executive Director of the National Board shall have an audit made of the NBIC Committee’s activities to ensure these procedures are followed. The audit shall be conducted by person(s) who are not members of the NBIC Committee. The audit report and follow-up action of deficiencies uncovered by an audit shall be reported to the NBIC Committee and the Chairman of the Board.

8.1.4 Patent Policy

The National Board shall comply with the ANSI patent policy as described in the ANSI Essential Requirements.

8.1.5 Commercial Terms

The National Board shall comply with the ANSI Commercial Terms and Conditions Policy as described in the ANSI Essential Requirements

8.1.6 Withdrawal of American National Standard

When required by ANSI Essential Requirements or the National Board elects to withdraw or discontinue an American National Standard or portion thereof, the National Board shall immediately notify ANSI for announcement in ANSI Standards Action. The National Board shall comply with all ANSI Essential Requirements for withdrawal of an American National Standard.

8.2 Revisions to the NBIC

8.2.1 Any interested person may request consideration of a revision to the NBIC

by submitting such request in writing to the secretary. If deemed editorial as determined by the secretary, requests will be incorporated into the NBIC draft edition for distribution and public review. Comments which are editorial in nature need not be submitted to the NBIC Committee or subcommittees for consideration prior to inclusion in the edition. Any public review comments associated with these editorial comments will be handled as such and will be considered by the NBIC Committee and subcommittee at the next scheduled meetings for final approval.


Attachment Page 46


Requests which are technical in nature will be forwarded to the appropriate subcommittee for consideration and recommendations made to the NBIC Committee, for their approval. Once approved, these revisions will be incorporated into the next draft. If approval is not reached, the item will be returned to the subcommittee for further action.

8.2.2 Following approval of a revision by the NBIC Committee and acceptance

under ANSI procedures, the approved revision shall be published in the next edition.

8.3 Interpretations of the NBIC

8.3.1 The NBIC Committee has the responsibility for interpreting and replying to

questions concerning the application of NBIC rule or guideline. Any interested person may request, in writing, an interpretation of a rule or guideline contained in the NBIC through the NBIC Committee secretary.

8.3.2 Upon receipt of such a request the NBIC Committee secretary determines

which subcommittee should develop a technical response.

When responding to questions concerning the interpretation of a rule or guideline, the following is to be used as a response:

“The NBIC was developed under procedures approved by the American National Standards Institute. The NBIC Committee that approved the NBIC and revisions thereto is a consensus NBIC Committee balanced to assure that individuals from competent and concerned interests have been afforded the opportunity to participate. Further, all proposed revisions to the NBIC are made available for public review and comment which provides an opportunity for additional input from jurisdictions, industry and the public at large.”

From time to time a request for interpretation regarding a superseded edition of the NBIC may be submitted to the NBIC Committee. If in the opinion of the members of the NBIC Committee, a response can be formulated, the NBIC Committee should respond to the inquirer's question. However, when it is the consensus of the NBIC Committee that a response cannot be formulated, the NBIC Committee should respond as follows:

“The (edition of the NBIC) has been superseded. The historical knowledge that the NBIC Committee feels is needed to respond to your request for interpretation is no longer available to the NBIC Committee.”

8.3.3 All interpretations of the NBIC shall be approved by the NBIC Committee. 8.3.4 All interpretations of the NBIC shall be posted on the National Board web

site. A written response will also be sent to the inquirer.


Attachment Page 47


8.3.5 The National Board accepts responsibility for, and recognizes only those

interpretations approved by the NBIC Committee.

8.4 Publications

8.4.1 NBIC

The NBIC shall be identified as "An American National Standard" and "ANSI/NB-23" in accordance with ANSI procedures. A new edition of the NBIC shall be published every two years. Each edition shall have a date of issue. The NBIC may be used beginning with the date of issue. Six (6) months after the date of issue, the edition becomes the requirement for compliance with NBIC. Complimentary copies of the NBIC will be provided to the members of the NBIC Committee, subcommittees, and subgroups.

8.4.2 Forms

National Board forms are part of the standard and follow the same requirements for revision as outlined in this procedure.

8.5 General

8.5.1 Referencing Other Standards

When the NBIC Committee wishes to reference another code or standard, the date of the specific, referenced code or standard shall not be cited unless required.

8.5.2 Copyrights

Copyright and all rights in all materials produced by the committee are owned by the National Board

9.0 Due Process

The National Board provides due process for the impartial handling of complaints regarding procedural or technical issues for any action or inaction. As part of this due process there are several levels to which an aggrieved party may appeal. This section gives criteria regarding right to appeal, how appeals are made and what may be appealed.


Attachment Page 48


At any level of the appeal process, there shall be no informal discussions between the body hearing the appeal and representatives of the appellant. Persons who have directly and materially affected interests and who have been or will be adversely affected by any procedural or technical action or inaction with regard to the development of a proposed American National Standard or the revision, reaffirmation or withdrawal of the NBIC have the right to appeal. Appeals shall be addressed promptly and a decision made expeditiously. The following process shall be followed:

a. Any person aggrieved by an interpretation, disposition of comments, procedural or

technical issues may appeal to the NBIC Committee.

b. The aggrieved person shall first request reconsideration by the NBIC Committee. Such request shall be in writing, addressed to the NBIC Committee secretary, and shall state the reasons for requesting reconsideration.

c. Should the person remain aggrieved following such reconsideration by the NBIC Committee or should such reconsideration be denied, the aggrieved person then, in writing, addressed to the National Board’s Executive Director, may request review by the National Board Appeals Committee. The findings of the National Board Appeals Committee operating under their procedures, shall be binding on the NBIC Committee as to the specific item under appeal and it shall be incumbent upon the NBIC Committee to consider incorporating the National Board Appeals Committee findings.

d. Should the person remain aggrieved following the National Board Appeals Committee’s decision, further appeal may be taken to the Board. Such appeal is initiated by a written request, addressed to the National Board’s Executive Director setting forth the grounds for such appeal. The appeal shall be heard at the next regular or special meeting of the Board which is held at a time of sufficient duration following such request as to allow distribution of all relevant documents and materials to the Board members. The Board, upon considering such appeal, by affirmative majority vote of those present, may allow a variance, may direct the NBIC Committee to consider a revision, or may sustain the action of the National Board Appeals Committee. The decision of the Board of Trustees on such appeal shall be final.

10.0 Records

Records shall be retained for a minimum of five (5) years or until approval of the subsequent revision or reaffirmation of the complete standard. Records for withdrawn standards shall be retained for a minimum of 5 years after withdrawal or until the next ANSI audit, whichever is longer.


Attachment Page 49


11.0 Antitrust Policy

The National Board of Boiler and Pressure Vessel Inspectors shall comply with the ANSI Antitrust Policy as described in the most current version of the ANSI Essential Requirements.


Attachment Page 50

Interpretation IN15-0601

Proposed Interpretation

Inquiry: IN15-0601 Source: Mr. Nate Manzon, PMC Engineering Solutions Subject: NBIC Part 3 Section 3 Edition: 2013 Question 1: May installation of a flush patch in a pressure

retaining part be classified as a “Repair” if any of its attachment welds are made using a backing strip along with the welds receiving the same degree of volumetric examinations as original construction when the original vessel design and construction of the pressure retaining part did not use backing strips in its design and construction.

Reply 1: No. If backing strips were not considered and used in the original design and construction, and are used on the flush patch installation, the work must be classified as an Alteration.

Question 2: May installation of a flush patch in a pressure retaining part be classified as a “Repair” if any of its attachment welds are made using a backing strip along with the welds receiving a lesser or higher degree of volumetric examination such that the applicable flush patch butt weld design joint efficiency is lower or higher than original construction when the original vessel design and construction of the pressure retaining part did not use backing strips in its design and construction.

Reply 2: No. If backing strips were not considered and used in the original design and construction, and are used on the flush patch installation, and if the applicable joint efficiency of the weld made using a backing strip is lower or higher than that of the joint efficiency used on the original design, there would be a change in the joint efficiency applicable to design of the part which would mandate that the work be classified as an Alteration.

Committee’s Question:

If a flush patch plate in a pressure retaining item (PRI) is installed with attachment welds using backing strips and the attachment welds receive the same or higher degree of volumetric examination required by the original code of construction with no reduction in joint efficiency as original construction is this considered a repair?

Committee’s Reply:

Yes

Rationale: SC Vote

IN15-0601 SC RA 7-20-16Attachment

Attachment Page 51

NBIC Vote

IN15-0601 SC RA 7-20-16Attachment

Attachment Page 52

NB16‐0810

NBIC Part 3, Section 3, paragraph 3.4.3

EXAMPLES

OF ALTERATIONS

a) An increase in the maximum allowable working pressure (internal or external) or temperature of a

pressure‐retaining item regardless of whether or not a physical change was made to the pressure‐

retaining item;

b) A decrease in the minimum temperature;

c) The addition of new nozzles or openings in a boiler or pressure vessel except those classified as repairs;

d) A change in the dimensions or contour of a pressure‐retaining item;

e) In a boiler, an increase in the heating surface or steaming capacity as described on the original

Manufacturer’s Data Report;

f) The addition of a pressurized jacket to a pressure vessel;

g) Except as permitted in NBIC Part 3, 3.3.3 s); replacement of a pressure retaining part in a pressure

retaining item with a material of different allowable stress or nominal composition from that used in the

original design;

h) The addition of a bracket or an increase in loading on an existing bracket that affects the design of the

pressure‐retaining item to which it is attached;

i) The replacement of a pressure relieving device (PRD) as a result of work completed on a pressure‐

retaining item (PRI) that changes the resultant capacity to exceed the minimum required relieving

capacity (MRRC) required by the original code of construction as described on the original Manufacturer’s

Data Report.

j) In a Heat Recovery Steam Generator (HSRG), an increase in heat input (e.g. adjustments or modification

to a Gas Turbine which increases the exhaust energy or the addition of or an increased firing rate of duct

burners).

IN16-0801 Troutt 10-17-16Attachment

Attachment Page 53

IN16-1001 12-19-16

-------------------------------------------- QUOTE --------------------------------------------

3.4.3 EXAMPLES OF ALTERATIONS …..

h) The addition of a bracket or an increase in loading on an existing bracket that affects the design

of the

pressure-retaining item to which it is attached;

…..

----------------------------------------- QUOTE END -----------------------------------------

Edition : 2015

Question 1 : If an increase in loading on an existing bracket cause only increase of local stress in

pressure part without physical change (reinforcing) of pressure part,

is the requierment of Alteration applicable as per 3.4.3 h)?

Question 2 : In 3.4.3 h), does the word 'pressure-retaining item' include an existing braket itself (non-

pressure part)?

IN16-1001 Jeang 12-19-16Attachment

Attachment Page 54

IN16-1101 12-19-16 We would like to have code interpretation on the NBIC Part -3 code cl. 57.3 and Figure 5.7.5 b Inquiry: In case of alteration of Heat Exchanger - Tube side only, is it allowed mention MAWP for tube side only on the Alteration nameplate, as alteration was done only on tube side. Reply: Yes or No Background: Repair organisation added 3 nozzles on Tube side of the Heat exchanger and shell side was not touched. Since alteration nameplate needs to mark with MAWP, is it allowed to mention MAWP only on Tube side as the work was carried out only on Tube side. The word Tube side also can be punched below MAWP. Hope to receive your kind reply. With best regards, Pradeep Subhedar

IN16-1101 Subhedar 12-19-16Attachment

Attachment Page 55

IN16‐1201 12‐19‐16

Back ground information:

We did a routine repair on a pressure vessel by replacing a window patch with a nozzle in the

bottom head of the vessel. The vessel has been fabricated with the 1956 edition of the

ASME/BPVC and the original material of the head is ASTM A‐201‐A. The repair was made

according to the 1998 edition of the code using the stress values of the 1952 edition. The

material of the new part is SA‐516 Gr 70N with the same minimum thickness as the original

head. The only document available was the G.A of the vessel.

Inquiry #1 : If we do a routine repair according to NB‐23, section 3.3.2, of a vessel using a

material with a greater allowable stress, according to the actual code, and keeping the same

minimum thickness of material, do we need to perform new calculation?

Reply #1 : Yes or No

Inquiry #2 : When we do calculation for alteration or repair and the code of construction used to

build the vessel is a previous 1999 edition, can we use the actual code of construction with

greater allowable stress values ?

Reply#2 : Yes or No

Inquiry #3: If the answer is no, de we have to use the most applicable code edition previous

1999 with the old allowable stress values if you don’t have access to the original edition of the

code of construction ?

Reply #3 : Yes or No

Hubert Beaudoin, ing.

+1‐514‐650‐4135

[email protected]

IN16-1201 Beaudoin 12-19-16Attachment

Attachment Page 56

IN16‐1301 12‐21‐16 Jeremy Napier Koch Industries

Purpose To determine if a liquid pressure test must be deemed impracticable before NDE can be performed to verify the integrity of repairs to pressure retaining items and connecting welds of replacement parts.

Scope: Examination and test requirements for Repairs as outlined in NBIC Part 3, paragraph 4.4.1 and for Alterations as outlined in NBIC Part 3, paragraph 4.4.2.

Background See attached letter.

Proposed Interpretation and Replies

Question 1: Does the NBIC Part 3 require that a liquid pressure test be deemed not practicable before the Inspector may accept (subject also to Jurisdictional acceptance when required) nondestructive examination per paragraph 4.4.1(e) to verify the integrity of a “repair”?

Proposed Reply: No

Question 2: Does the NBIC Part 3 require that a liquid pressure test be deemed not practicable before the Inspector may accept (subject also to jurisdictional acceptance when required) nondestructive examination per paragraph 4.4.1(e) to verify the integrity of “connecting welds”, as defined in paragraph 4.4.2 (a)(2) for an “alteration”?

Proposed Reply: No

IN16-1301 Napier 12-21-16Attachment

Attachment Page 57

IN16-1301 Napier Background Information 12-21-16Attachment

Attachment Page 58

IN16-1301 Napier Background Information 12-21-16Attachment

Attachment Page 59

NB12-0801 Failed Letter Ballot Comments 11-3-16Attachment

Attachment Page 60

Letter Ballot item: NB12-0801- Repair or Alteration of Plate Heat Exchangers Comment: Reluctantly, I will vote to “disapprove” this item, as I believe the critical nature of material selected in original design and manufacture is not adamantly communicated to the stakeholders of the code. Having the benefit of an extended review with the PM, it is very apparent the manufacture of plate heat exchangers is very unique and at times proprietary, deserving of an approach somewhat reminiscent of the guidance offered in the PRD-Supplement. To my disapproving vote, I would like to offer the noted changes as shown for Subcommittee consideration. –M. Webb, 10-7-16. 3.3.3 EXAMPLES OF REPAIRS u) For plate heat exchangers (PHE’s), repair activities are those actions necessary in replacing

parts bearing certification or manufacturer’s stamping with no-change in material allowed for parts as described on the Manufacturer’s Data Report (MDR) or verifiable Original Equipment Manufacturer’s (OEM) drawing. Repair activities for PHE’s are further described or limited to: in addition to all of the applicable examples of repair above:

1) Welding on any pressure part;

2) In kind replacement of endplates, welded nozzles,

3) The addition or repair of load bearing attachments (e.g., welded supports or lifting lugs)

to the endplates.

3.4.3 EXAMPLES OF ALTERATIONS j) For plate heat exchangers (PHE’s), in addition to all the applicable examples of alterations

above, the following changes from what is listed on the MDR or described on the Original Equipment Manufacturers (OEM)-drawing:

1) For heat transfer plates:

a) A change in material grade or nominal thickness; b) A reduction in number beyond any minimum, or when no minimum is specified; c) An increase in number beyond any maximum, or when no maximum is specified; d) A change in model type;

2) Any change in material whether described at 3.3.3 s) or as described at 3.4.3 g): a) A change in connection bolt or frame compression bolt diameter or material grade; b) A change in material grade or nominal dimensions of any end plates or nozzles.

NB12-0801 Webb Suggestions 11-3-16Attachment

Attachment Page 61

of 3

Subgroup Locomotives National Board Item No. NB13-1405 Current Level: Subcommittee Repairs and Alterations NBIC Part 3 Paragraph(s): S1.2.14 Title: Throttle Pipes, Dry Pipes, Superheater Headers & Front End Steam Pipes Date Opened: April 2013 Background: The reason for adding this section is to provide guidance for repair of these locomotive boiler components. Two accidents have occurred to steam locomotives over the past 30 years when the dry pipe collapsed and caused the locomotive to operate out of control. Although neither accident caused injury equipment damage did occur. In addition other accidents that resulted in injury and fatalities have occurred to steam locomotives during the years of 1910 - 1950 when these were in normal railroad service. Proposed Action:

Throttle Pipes, Dry Pipes, Superheater Headers & Front End Steam Pipes 1) Throttle pipes, dry pipes, superheater headers, and front end steam pipes made from cast iron and have cracks greater than 0.25 inches (6 mm) in length or width or have corroded to less than the minimum allowable thickness shall be removed from service. Cracks not exceeding 2.00 inches (50.8 mm) in length or 0.25 inches (6.4 mm) in width may be repaired by brazing. Pinholes and defects not exceeding 0.25 inches (6.4 mm) in diameter may be repaired by brazing. Repair by brazing of cracks and defects exceeding these limits may be made only with the approval of the Inspector. If the brazed metalrepair enters into the interior of components subject to steam flow, the interior repaired surfaces should be ground smooth to prevent any braze metal protusion between the original and repaired surfaces. Repairs using other methods may be made using NBIC Part 3, 3.3.4.8 "Repair Of Pressure-Retaining Items Without Complete Removal Of Defect" and NBIC Part 3, 3.2.6 "Reference To Other Codes And Standards". 2) Cracks in throttle pipes, dry pipes, superheater headers, and front end steam pipes made from steel may be repaired by welding. All welded repairs shall be done in accordance with NBIC Part 3 and ASME Section I Part PW. The welds shall be full penetration-type and shall be volumetrically examined when required by the applicable NBIC or ASME code requirements, and when required by the Inspector. 3) Weld build-up may be used for repair of steel components provided the corroded section does not exceed 10 square inches (64.52 square centimeters) in area and the depth of corrosion is less than 50% of the original wall thickness. If the corrosion depth or area exceeds one or both of these values, either the corroded section shall be replaced by a new section installed using full penetration welds or the

Formatted: Left: 0.7", Right: 0.7", Top: 0.5", Bottom: 0.5"

NB13-1405 10-31-13 SG LocomotiveAttachment

Attachment Page 62

of 3

entire component replaced. All weld build-up repairs shall be done in accordance with NBIC Part 3 and ASME Section I Part PW. Welds shall be volumetrically examined when required by the applicable NBIC or ASME code requirements and when required by the Inspector. If the weld build-up enters into the interior of components subject to steam flow, the interior welded surfaces shall be ground smooth to prevent weld metal protusion between the original and repaired surfaces. 4) When new replacement sections or flush patch plates are installed in steel components the interior edges of the new and original surfaces subject to steam flow shall be aligned and level with each other and should be ground smooth to prevent forming raised edges. Welds shall be full penetration-type and shall be in accordance with NBIC Part 3 and ASME Section I Part PW. The welds shall be volumetrically examined when required by the applicable NBIC or ASME code requirements, and when required by the Inspector. Replacement flanges may be installed by welding in accordance with NBIC Part 3 and ASME Section I Part PW. 5) Throttle pipes, dry pipes and superheater headers, shall be supported by hangers, brackets or other structural method to prevent placing bending loads on the adjacent mating parts and attachment fasteners. When required by the original design, pins, bolts and nuts used to attach these parts and to each other and to the boiler shall be equipped with a retainer or another method to prevent loosening. Changing the location, number, size, or design of the hangers, brackets or other structural method and the associated fasteners used to support the throttle pipe, dry pipe or superheater header is considered an alteration. 6) Front end steam pipes shall be arranged to fit into position on adjacent mating parts and attachment fasteners without being forced and without bending or damaging the attachment fasteners. Changing the location, number, size or design of the fasteners used to secure the front end steam pipes is considered an alteration


Attachment Page 63

of 3


Attachment Page 64

July 27, 1936, locomotive 4405, Mazama, ureg. \.iUlUe YUKe UW"-t: ULlt: w

old fracture in bottom bend covering approximately 90 percent of cross-sectionalarea; one injured.

**September 26,1936, locomotive 4014, near Cascade Summit, Oreg. Undesiredemergency application of the brakes, caused by defective vent valve on tender;one injured.

*October 18, 1936, locomotive 2806, Surf, Calif. Insufficient clearance between throttle lever and valve on boiler head; one injured.

October 18, 1936, locomotive 3243, Gridley, Calif. Eccentric rod broke; oldfracture covered approximately 50 percent of cross-sectional area; one injured.

*November 17, 1936, locomotive 2350, Volta, Calif. Insufficient clearancebetween reverse lever and feed valve bracket; one injured.January 4, 1937, locomotive 1787, Berenda, Calif. Injector throttle valve

bonnet blew out due to poor fit in valve body; one injured.*January 23, 1937, locomotive 4401, Suisun-Fairfield, Calif. Glass in cab

storm window broke; one injured.**April 8, 1937, locomotive 1273, Oakland, Calif. Lubricator plug bushing

broke off at seat on lubricator; old cracks in bushing; one injured.April 11, 1937, locomotive 4322, Randolph, Ariz. Stearn pipe sleeve at water

column connection failed at fillet between sleeve and flange; steam pipe notbelled or flanged over end in accordance with company's standard practice andbrazing between pipe and sleeve extended only about three-fourths inch fromtop of sleeve, permitting pipe to pull out of coupling nut when sleeve failed;defective installation of steam pipe resulted in strain on pipe and sleeve. Aheavy deposit of bronze had been applied by fusion welding just above sleeve inan attempt to repair a circumferential crack in steam pipe; two injured.

*April 16, 1937, locomotive 4367, Argo, Nev. Driving wheel tire broke dueto thermal crack; one injured.

*April 29, 1937, locomotive 4324, Curvo, Ariz. Feed water pump did notoperate properly; one injured.

May 9, 1937, locomotive 3265, Malaga, Calif. Water glass burst; water-glassframe not true and water glass had been filed in attempt to fit it to frame. Inattempting to escape from the steam and water, the firing valve was inadvertentlyopened wider and fire suddenly backed through firebox door of oil burning locomotive in such volume that it spread over oil tank and badly damaged first car;two injured.

*June 3, 1937, locomotive 3762, Massie, Nev. Rear axle of tender broke atold fracture, causing derailment of 15 cars; two killed.June 16, 1937, locomotive 1209, East Portland, Oreg. Explosion of accumulated

gases in firebox while cleaning carbon from firebox; "Clean carbon out of firebox"was reported 22 times since June 1; one injured.

Fifteen accidents; 2 killed, 17 injured.

TENNESSEE, ALABAMA & GEORGIA RAILWAY:

December 3,1936, locomotive 301, Pigeon Mountain, Ga. Sand pipes cloggedaccount of sand being wet; one injured.

One accident; one injured.

TENNESSEE CENTRAL RAILWAY:

*June 7. 1937, locomotive 505, Stone River, Tenn. Brake hanger broke;one injured.


TERMINAL RAILROAD ASSOCIATION OF ST. LOUIS:

**March 16, 1937, locomotive 330, St. Louis, Mo. Coal board split, causingemployee to fall; one injured.


TEXAS & PACIFIC RAILWAY:

**February 23, 1937, locomotive 909, Mineola, Tex. Employee scalded bydischarge from blow-off cock which was apparently accidentally opened and bysteam from cylinder cock which was held open by pieces of broken cylinderpacking ring; one injured.

April 21, 1937, locomotive 458, Shreveport, La. Insufficient clearance betweencab handhold and tender deck; one injured.

May 21, 19~7, locomotive 603, Edgewood, Tex. Steam pipe in front end burst;upper wall of 90° angle in the cast iron steam pipe was reduced from % inch toabout ~ inch in thickness; steam pipe not company's standard; one injured.

'.

and ~~:;e;'Ct~ -f~li forward position, catching employee's leg betweenfoot brace; valves dry and teeth in quadrant worn; one injured.

Four accidents; four injured.

UNION PACIFIC RAILROAD:

July 24, 1936, locomotive 9080, Baxter, Wyo. Left guide rail of rniddcrosshead fell from locomotive and became wedged on track, resultingment of 26 cars of a mixed train; right guide rail had previously fallen of'all guide bar bolts were missing; bolt holes in guide bars and rails wer.and elongated; bolts reported repeatedly since July 1; two killed.

**August 3, 1936, locomotive 7008, near Seymour, Nebr. WOOl(provided to be used to relieve the weight from driving boxes when jourfell from locomotive and struck track employee; one injured.January 14, 1937, locomotive 2301, Ault, Colo. Fire tube failed a,

weld; one injured.March 30, 1937, locomotive (0. W. R. & N.) 2152, Dodson, Oreg.

steam pipe sleeve at connection to cab turret steam valve failed in aibreak for its full circumference; sleeve greatly overheated at time of aand brazing between steam pipe and sleeve did not extend full lengthone injured.

**April 19, 1937, locomotive 1931, Frankfort, Kans. Governor pcompressor broke off at connection to governor; pipe not properly cla:injured.June 6, 1937, locomotives (0. S. L.) 9509 and (U. P.) 3601, Mans:

Locomotives uncoupled, causing emergency application of the brakes; 01June 9, 1937, locomotive (0. W. R. & N.) 4913, Albina, Oreg. Tendc

at crossover, caused by spring buffer slipping by corner of wearing plateblock while rounding curve; shoulder on wearing plate did not peribuffer to return to normal position after coming out of curve; one injur

Seven accidents; two killed, six injured.

WABASH RAILWAY:

January 3, 1937, locomotive 2917, Adrian, Mich. Crown sheet failiby overheating due to low water; top water-glass cock was closed ;,accident; three killed.

**February 27, 1937, locomotive 1562, St. Louis, Mo. Insufficientbetween vertical handhold at back of cab and tender deck when on sh.one injured. .

April 1, 1937, locomotive 603, near Sturgeon, Mo. Reverse lever unl«went forward rapidly, striking employee's foot; one injured.

**April 11, 1937, locomotive 2919, Peru, Ind. Dump grate plate b'part of plate missing; one injured.Four accidents; three killed, three inj ured.

WESTERN MARYLAND R.HLWAY:

August 8, 1936, locomotive 1126, near Confluence, Pa. Driving sprigib broke or lost out, throwing excessive weight on one side of locomo!resulted in derailment of locomotive and tender; one injured.

April 11, 1937, locomotive 921, George's Creek Junction, Md. Air Iinoperative; cotter key for attaching plunger to piston sheared off; on

Two accidents; two injured.

WESTERN PACIFIC RAILRO.\D:

*February 28, 1937, locomotive 40, Keddie, Calif. Reverse lever lat

one inj ured.One accident; one injured.

NB13-1405 Additional Information Stone 10-26-16Attachment

Attachment Page 65

..56 REPORT OF THE CHIEF INSPECTOR OF LOCOMOTIVES

Texas & Pacific AccidentMay 21, 1937

PLATE 11

Plate 11 shows a front-end steam pipe that failed while the locomotive was hauling a passenger train ata speed of approximately 45 milesper hour. The fireman had his foot on the pedal of the mechanicallyoperated fire door and was looking at the fire at the time of failure which instantly filled the cab with fireand gas. The fireman was severely burned but the automatic closing of the door when his foot was removed from the pedal shut off the flow of fire and gas from the firebox and undoubtedly saved him fromfatal injuries. The engineer, who was not seriously injured, was enabled to stay in the cab and closethe throttle and apply the brakes.

NB13-1405 Additional Information Stone 10-26-16/Page 2/Images/Image 1Attachment

Attachment Page 66

I

iiI!

12 REPORT OF THE CHIEF INSPECTOR OF LOCOMOTIVES

**December 20, 1937, locomotive 2003, Thomo.sville, Ga. Defective conveyorslide hook slipped out of hole in conveyor slide when employee attempted to close

the slide; one injured.Fcbruary 22, 1938, locomotive 1520, near Selma, N. C. Driving spring hanger

broke; one injured.March 3, 1938, locomotive 1659, Stony Creek, Va. Cast iron steam pipe at

front end burst; thickness of pipe at point of failure varied from 1-%6 inches to~16 inch; steam pipe contacted side of smoke box, preventing free expansion of the

pipe; one injured.Four accidents; four injured.

BALTIMORE & OHIO RAILROAD:

**August 15, 1937, locomotive 6159, GR Cabin, Ohio. Piece of sheet metalforming an inside shield over cab window jarred loose from its fastening to cabwall and swung down, striking employee; one injured.'October 23, 1937, locomotive 4266, Ribold, Pa. Stoker slide hook disengaged

from slide plate; hook not proper fit in holes in slide plate; one injured.November H), 1937, locomotive (B. & O. C. '1'.) 2856, Chicago, Ill. Injector

steam pipe collar broke off in spanner nut at injector thrott.lc valve connection;end of ~tealll pipe not belled over collar; proper repairs not made when spannerHut was reported leaking on 1'\ ovember 3, fi, and 18; two inj ured.February 12, If)38, locomotive 6221, Bakerstown, Pa. Hiuges of tender cistern

.filling hole cover broke through rivet holes; one injureci.April 25, 1938, locomotive 5138, Mt. Vernon, Ohio. Penstock hook bent, caus

ing employee to fall from tender; hook badly pitted and rusted away; hook was not

company's standard; one injured.June 11, 1938, locomotive 7115, Keyser, W. Va. Side rod collar bolt broke and

was thrown from locomotive, striking a pedestrian; one injured.Six accidents; seven i nj ured.

BOSTON & l\'!AINE RAILROAD:

**Augu~t 12, 1937, locomotive 1364, East Lynn, Mass. Push pole lying on

rear of tank behind fuel space; one injured.December 29, H)37, locomotive 2723, Westboro, N. H. Bonnet of feed water

pump throttle valve became disconnected from valve body; one injured.March 16, 1938, locomotive 3029, Scotia, N. Y. Tool box which was attached

to back cab wall fell account of bolts breaking; bolts for securing tool box weresmaller than company's standard and one of the two bolts had been broken for

some time; one injured.May 6, 1938, locomotive 1498, Waltham, Mass. Cab apron worn; one injured.=May 26, 1938, locomotive 3653, North Billerica, Mass. Lubricator steam

pipe pulled out of sleeve of the union connection to throttle valve; pipe not

properly brazed in -leeve ; one injured.May 31, 1938, locomotive 4020, East Deerfield, Mass. Fireman lost his

balance and fell from top of tender while attempting to take water; water spoutout of reach and no means available to pull it around; one injured.

Six accidents; six inj ured.

CENTRAL OF GEORGIA RAILWAY:

June 14, 1938, locomotive 710, Sylacauga, Ala. Employee's hand cut by

broken glass in cab door; one injured.'One accident; one injured.

CENTRAL RAILROAD OF NEW JERSEY:

July 22, 1937, locomotive 787, Hazlet, N. J. Driving box grease cellar guardplate was thrown from moving locomotive and through a window in a passengercar in a train on adjacent track; holes in grease cellar inside lugs not drilledaccording to company's standard; threads in keeper bolt hole in poor condition;cellar bolt and cellar bolt hole worn; one injured.November 19, H)37, locomotive 874, Bloomsbury, N. J. Locomotive separated

from train, resulting in sudden stop; rear coupler top lock lifter worn, permittingcoupler lock to function and knuckle to open; one injured.

**June 29, 1938, locomotive 159, Sea Bright, N. J. Brake hanger guard wasthrown from tender and struck an automobile which was near rail crossing,

.. , .. _.. ,~ ,'h~ rl~;,,"r "f thp <I.llt.()mohile: one injured.

REPORT OF THE CHIEF INSPECTOR OF LOCOMOT

CHICAGO & EASTERN ILLINOIS RAILWAY:

*October 6, 1937, locomotive 1945, St. Anne, Ill. Main crankfracture extended over approximately 80 percent of cross-sectionalof failure; one injured.One accident; one injured.

CHICAGO & NORTH WESTERN RAILWAY:

November 24, 1937, locomotive 2361, Ames, Iowa. Fire tub:safe end weld; overheated in welding; one injured.

*January 25, 1938, locomotive 2068, Hawarden, Iowa. Drainpipe under right boiler check stopped up; one injured.Two accidents; two injured.

CHICAGO, BURLINGTON & QUINCY RAILROAD:

July 29, 1937, locomotive 5057, Denver, Colo. Water glass bursNovember 16, 1937, locomotive 7015, Sandwich, Ill. Air pi

employee fell from side rod while attempting to open steam thremergency air pump which was located under running board; "Air 1slow and stopping" was reported on October 27; one injured.

December 6, 1937, locomotive 2585, near Canton, Ill. Blow-off (rod handle was loose; one injured.Three accidents; three inj ured.

CHICAGO GREAT ""ESTERN RAILROAD:

October 23, 1937, locomotive 476, South Des Moines, Iowa.burst; one injured.January 22, 1938, locomotive 882, Bolton, Ill. Top portion of

of No.4 driving box shoe broke off and struck sectionman whoabout 60 feet from the track; "All driving boxes pounding bad" allright I\ o. 4 dri ving box wedge." were reported on January 9, 12, U ..one injured.January 28, 1938, locomotive 877, Melbourne, Iowa. Crown

caused by overheating due to low water; two killed, one injured.March 1, 1938, locomotive 478, Waterloo, Iowa. Water glas

missing from one side of water-glass guard; one injured.April 17, 1938, locomotive 88-1, Oneida, Iowa. Derailment cal

cated driving wheel tires; tires overheated due to brake friction; th**May 6, 1938, locomotive 750, Weitman, Iowa. Injured whi

to adjust rib of stoker divider which had moved to left side; lock I

was loose; one injured.Six accidents; two killed, eight injured.

CHICAGO, J.\:hLWAUKEE, ST. PAUL & PACIFIC RAILROAD:

*May 3, 1938, locomotive 2600, Belvidere, S. Dak. Light inlamp inoperative account of bulb not properly screwed in socket; (

May 20, 1938, locomotive 8073, Tomah, Wis. Injector steamnut at injector connection broke into two pieces; old fracture CO\

mately 75 percent of one of the breaks; one injured.Two accidents; two injured.

CHICAGO, ROCK ISLAND & PACIFIC RAILWAY:

August 14, 1937, locomotive 3025, McAlester, 'Okla. Insuffici.between vertical cab handhold and tender deck supporting block wl

one· injured.. September 11, 1937, locomotive 1550, Camden, Ark. Crowncaused by overheating due to low water; one killed.December 20, 1937, locomotive 902, Blue Island, Ill. Air hose at I

was ruptured; one injured.January 3, 1938, locomotive 2507, Clearing, Ill. Cab steam he:

was frozen; one injured.**February 1, 1938, locomotive 2051, Limon, Colo. Employee',

on edge of cab apron while ascending gangway steps; apron proje:gangway step when on curve; one injured.

March 5, 1938, locomotive 4055, Lawrence, Kans. Main cranthrough old fracture covering approximately 75 percent of cross-se

1 " __ •• __ "- __ 1. __ ...•• 1=__ 1__ ..l c __ t)() ..-In __ .......... _ .............. ....J; ......... +hn


Attachment Page 67

52 REPORT OF THE CHIEF IXSPECTOR O.F LOCO~IOTIVES

Atlantic Coast Line AccidentMarch 3, 1938

1'1. \TE IIi.

1'1.1:<' IIi ,II,)\I";·I l"I,I·ir"l1 :·I'llnr l'n,I";I'':lln pipe llI:11 f:liled whilo Ilw ICl('IlIIlOlil(, \1·:1, h,lIII;Il.~:1 fr.'i ... lu t r.iu.'l! :! < 1'1'l'd "r :IPI'I'()\ i m.u cl" :ill Illi ie..; I'l'r 1101 I I'. I'!,"; ulI i ll~ ill I Ill' ..;priIHI"; i lljl 11':, of oru- l'lllplo\'pt' T he fa i IIII't'(lri"ill'll!'d ill all '11'1',1 w lu-rv t h» \I:ill of t he pipe ,,·,I.';";"I·t'Il·,i\:I'8111[\..; invh ill Ihil'kIlP";';.lhl' 1'l'lIlaindE'[' ofi he pip!' I·ari!'d f["'11l [lp·I'I'·follrrlI, 1II'II1l' a nd t hrcc-sivt ee m h« i ncho« in I hick [\("";. Tile pipe had heeu,Ipplil'd wit h t he t hi n :\1'(',1 be.ui ne he.i vi lv 011 I hi' ";llIlIke ho\.

REPOR'

NB13-1405 Additional Information Stone 10-26-16/Page 4/Titles/REPORT OF THE CHIEF IXSPECTOR O.F LOCO~IOTIVESAttachment

Attachment Page 68

18 HEPOHT OF THE CHIEF IKSPECTOR OF LOCOMOTIYES

DELAWARE, LACKAWANNA & WESTERN RAILROAD:

June 8,1937, locomotive 2141, Hallstead, Pa. Valve rings broken; one injured.Onc accident; one injured.

DE:-IVER & RIO GRANDE 'WESTERN RAILROAD:

August 17, 1936, locomotive 1703, Midvale, Utah. Radius rod broke; oldfracture covered approximately 50 percent of cross-sectional area; one injured.

**December 7, 1936, locomotive 1503, Agate, Utah. Squirt hose valve accidentally opened; valve improperly located; one injured.

December 12, 1936, locomotive 3415, Sierra, Colo. Top board and supportingbrackets at rear of tender coal space out of proper alignment; one injured.

**December 22, 1936, locomotive 1190, Grand Junction, Colo. Throttle diffi-ult to operate; throttle reported on December 21, 22, 23 (two times), 25, and 27;

o ne injured.**December 27, 1936, locomotive 1151, Helper, Utah. Reversing gear difficult

to operate account of valves being dry; dry pipe and/or throttle reported Icaking13 times since December 1; one injured.March 1, 1937, locomotive 1705, Brendel, Utah. Left main pin failed due to

lid fractures; left main rod reported pounding on February 9, 11, 25, and 27; one

injured.June 26, 1937, locomotive 1148, Kaysville, T'tah. Lost footing due to rough

-iding locomotive; one injured.Seven accidents; seven injured.

ERIE RAILROAD:

August 10, 1936, locomotive 3323, Cameron, K. Y. .Main steam pipe in front=nd burst; thickness of steam pipe walls varied from % inch to 1% inches, due todefective casting, and side wall contained an air pocket approximately 7}~ inches'eng and metal on sides of this pocket was about }16 inch thick; t.hree injured.

*August 10,1936, locomotive 1767, Mo nterev, Ind. Reverse lever jerked fromemrlO~'ee's grasp and went to corner, striking his leg; valves dry; one injured.

*?\ovemb"r 20,1936, locomotive 2707, Osborn, Ohio. Air hose on tender burst;one injured.

December 21,1936, locomotive (N. Y. S. & w.: 34, Avon, K. Y. Handrailhroke off at both ends due to being fractured at both fittings and wasted away toabout ~~2 inch in thickness at root of threads; one injured.

January 27, 1937, locomotive 3338, Akron, Ohio. Insufficient clearance between fire door pedal and hinge on door over stoker transfer hopper; one injured.February 18, 1937, locomotive 2027, Buffalo, N. Y. Reverse lever jerked while

being moved; right valve was dry and binding due to rings too tight account ofsxcessive carbon in valve chest and valve body; link blocks worn; reverse leverlatch handle was badly bent, due to connecting straps between handle and dogbeing too short, preventing proper hold on lever; one injured.

March 4, 1937, locomotive 3333, Shongo, N. Y. Stoker elevator pawl shifterwould not latch in neutral position account of catch pin missing; one injured.June 30, 1937, locomotive 4017, Marion, Ohio. Bell ringer inoperative; one

injured.Eight accidents; 10 injured.

FLORIDA EAST COAST RAILWAY:

January 15, 1937, locomotive 702, Fort Pierce, Fla. Handrail broke due to old:racture; one injured.


FORT WORTH & DENVER CITY RAILWAY:

January 24, 1937, locomotive 456, near Wichita Falls, Tex. Squirt hose valveworked open; insufficient means for holding squirt hose in position when not inuse; valve insufficiently packed and packing dry, permitting valve handle towork open; one injured.


GRAND TRUNK WESTERN RAILWAY:

*August 15, 1936, locomotive 3741, Stillwell, Ind. Piston rod broke throughflaw at keyway in crosshead fit; 1 injured.

November 11, 1936, locomotive 3737, Port Huron, Mich. Oil feed pipe to aircompressor failed near lubricator connection; one injured.

December 31, 1936, locomotive 6039, Perry, Mich. Main crank pin brokeiust inside wheel fit; old fracture covered 75 percent of the area of the crank pin;'wo injured.

Three accidents; four injured.

HEPOHT OF THE CHIEF l~SPECTOn OF LOC0:\IOTlVES 19

GREAT NORTHERN RAILWAY;

**November 19, 1936, locomotive 1702, Northtown Junction, Minn. Reverselever jerked violently forward, shearing stop bolt in quadrant and going to extremeforward end of quadrant where it stuck; one injured.

**December 12, 1936, locomotive 3048, Howard Lake, Minn. Mechanicalstoker failed to function due to bucket chain becoming stuck in elevator housing;one injured.

March 27,·1937, locomotive 1458, Stanwood, Wash. Driving spring hangerbroke at gib hole; approximately 40 percent of break was old fracture; one injured.June 12, 1937, locomotive 2124, near Blaisdell, N. Dak. A piece of cast iron

steam pipe in smoke arch, approximately 13 by 25 inches, blew out; failure originated at a vertical crack that started from the inside of pipe; thickness of steampipe walls varied from % inch to 1Yt6 inches, due to core being improperly placedin casting. A 12-inch crack in pipe wall opposite the failure had been repairedby fusion welding; one injured.

Four accidents; four injured.

GULF, COLORADO& SANTA FE RAILWAY;

January 19, 1937, locomotive (A. T. & S. F.) 1385, Berwyn, Okla. Headlightburned out; headlight step not conveniently located; one injured.February 5, 1937, locomotive (A. T. & S. F.) 1266, near Arlington, Tex. Main

crank pin broke off due to old fracture covering approximately 80 percent ofcross-sectional area; one inj ured.

June 23, 1937, locomotive (A. T. & S. F.) 3923, Cozart, Tex. Main pin brokeat inside of main rod bearing; 80 percent old fracture; one injured.

Three accidents; three injured.

ILLINOIS CENTRAL RAILROAD:

November 17, 1936, locomotive 1853, Pinckneyville, Ill. Defective wirecovering on air hose for cleaning cab caught on nail head projecting from deckand pulled the nail out. The nail flew up and struck engineer's eye, resulting inprobable permanent disability; one injured.

December 5, 1936, locomotive 1085, Sitka, Tenn. Fire door frame stud blewout; not more than one-half thread had been tapped in stud hole in boiler backhead and stud had been screwed into sheet only about three and one-half threadswith threads mutilated; one injured.

December 14, 1936, locomotive 265, New Orleans, La. Insufficient clearancebetween cab handhold at gangway and tender deck; one injured.February 13, 1937, locomotive 2013, Gordon, Ill. Fire door pedal improperly

located; one injured.February 17, 1937, locomotive 1895, Cruse, Ill. Locomotive uncoupled from

train due to low coupler on rear of tender; one injured.May 1, 1937, locomotive 558, Bossier City, La. Pipe from main reservoir to

high pressure head of air-compressor governor broke off at collar of union togovernor; one injured.

May 17, 1937, locomotive 3562, Memphis, Tenn. Water glass burst; oneinjured.June 29, 1937, locomotive 1531, Fonda, Iowa. Fire-door pedal moved out of

position when adjustable latch became disengaged, causing employee to fall; firedoor hanger bolt cotter key missing; one injured.Eight accidents; eight injured.

INDIANA HARBOR BELT RAILROAD:

*April 2, 1937, locomotive 408, Hammond, Ind. Glass in cab storm windowbroke; one injured.


INTERNATIONAL-GREAT NORTHERN RAILROAD:

October 21, 1936, locomotive 342, Palestine, Tex. Axle broke inside the hubof left main driving wheel; old fractures covered approximately 36 percent ofcross-sectional area at point of failure; wheel improper fit and had been workingon axle. Locomotive was returned to service on date of accident after havingbeen removed account of left main wheel loose on axle; one injured.


KANSAS CITY SOUTHERN RAILWAY;

August 21, 1936, locomotive 497, Baxter Springs, Kans. Fire tubes leakingat fusion welded beads to back flue sheet, caused by overheating due to accumulation of mud about 3 inches thick on back flue sheet. "Bad leaks in firebox"


Attachment Page 69

56 REPORT OF TIlE CHIEF Ii\'SPECTOR OF LOCO:\[OTIYES

Great Northern Railway AccidentJune 12 1937

PLATE 14

Plate J.! shows a east-iron front end steam pipe that failed while the locomotive was hauling a freight trainat a speed of approximately ~5 miles per hour, resulting in the serious injury of one employee ." The failureoriginated at a vertical crack that started from tbe inside of the pipe; the crack had apparently beenpresent for a considerable period of time.

, IPLATE 15

I'latc 15 shows brazing that had been applied in an attempt to repair a crack in tbe side opposite tbe breakin the steam pipe shown in plate 14.

NB13-1405 Additional Information Stone 10-26-16/Page 6/Titles/Great Northern Railway AccidentAttachment

Attachment Page 70

Members; I’ve attached the 1937 ICC summary of the photo of the front end steam pipe failure from my previous e-mail for your review along with the details of two additional accidents. These three failures show the potential for cast iron front end steam pipes to rupture and shatter through brittle fracture once a crack occurs. The potential for failure is increased when the steam pipe when is worn and when it is stressed as a consequence of being forced into assembly as a result of misalignment. The same cracking and rupture failure potential exists with the other cast iron locomotive boiler components, including the cab turret, if the part is worn or if its bolt flange or the associated piping components that attach to it are misaligned and then forced together at assembly. The existence of a crack in cast iron front end steam pipes and other cast iron locomotive boiler parts demonstrates that the part is life expired as result of wear and long term cyclic stress (long operating life) and now needs to be replaced. The repair of these cracked pressure vessel parts by welding or brazing is not feasible based the boiler industry experience to date. When a steel pressure vessel part cracks the crack may result in a bell mouth failure (the two sides of the cracked surface may spread open along the length of the crack) but usually without the massive rupture failure that occurs with cast iron parts. 1) The first front end steam pipe failure occurred on the Texas & Pacific on May 21, 1937. See the attached report summary and Picture/Plate #11. The front end steam pipe was made from cast iron and the ICC attributes the failure to it not being made to the company standard and also having a reduced wall thickness at the 90 degree bend. It is possible the front end steam pipe did not fit but was forced into position. The reduced thickness problem appears to have been caused by the combination of wear and a manufacturing problem in which the wall section that failed was cast thinner than the required design standard by the core shifting during the casting process. My analysis of the failure photograph is that the front end steam pipe did not fit up to the front tube sheet to enable it to make the connection to the joint ring at the superheater header. The connection was made by forcing the front end steam pipe into position. This twisted and strained the front end steam pipe at the large 90 degree bend and caused the cast iron pipe wall to crack along the radius at the bottom of the large 90 degree bend. The crack them spread out into two planes which met eventually and led to the rupture. The installation of this front end steam pipe was performed and approved by an experienced crew and the foreman in one of the T&P’s main shops or roundhouses. 2) The second cast iron front end steam pipe failure occurred on the Atlantic Coast Line on March 3, 1938. See the attached report summary and Picture/Plate #16. It was caused by the cast iron front end steam pipe bursting over a large area that had worn thin.

NB13-1405 Stone Comments 10-26-16Attachment

Attachment Page 71

This ICC assigns the primary failure to the front end steam pipe not fitting correctly and being forced into position. The defective installation placed a section of steam pipe pipe wall into direct contact with the smokebox wall. The contact caused this section of the front end steam pipe to wear thin until it burst. The wear occurred through abrasive wear created by the combination of vibration and thermal expansion of front end steam pipe against the smokebox wall during operation. The contact with the smokebox wall also limited free expansion of the steam pipe. The restricted expansion in turn created high stress in one section of the steam pipe wall which then created the initial crack once the pipe wall had worn thin. The defective installation of this front end steam pipe was performed and approved by an experienced crew and the foreman in one of the ACL main shops or roundhouses. It then passed subsequent inspections over a period of several months or years during which no one noticed that the front end steam pipe was misaligned and in direct contact with the smokebox wall and was becoming worn. These defective conditions continued unnoticed until the failure occurred. 3) The third cast iron front end steam pipe failure occurred on the Great Northern on June 12 ,1937. See the attached report summary and Pictures/Plates #14 & #15. It was caused by the front end steam pipe first cracking and then bursting over a large area that had both worn to a varying degree and was originally cast thin. The thin casting was caused by a manufacturing error in which the core shifted during casting process. This front end steam pipe had a history of cracking problems and had a previous crack repaired by some type of fusion welding. 4) The potential for cast iron locomotive boiler parts to crack is increased if the parts' bolt flange or associated piping components are misaligned and then forced together at assembly. I consider this to be a particular problem with the cab turret due to the limited inspection that it usually receives during overhauls. The original draft for NB13-1405 included a section requiring "the front end steam pipes to be aligned and assembled without being forced into position”. Our committee removed this rule as unnecessary but I recommend it be reinstated back into NB13-1405 to inform and warn NBIC inspectors and users of the failure potential for cast iron front end steam pipes when they are worn or misaligned. I would like our groups’ NBIC inspector members Paul Welch and Mark Jordan to comment on this item since I consider the cracking potential of cast iron boiler fittings and piping to be necessary information for an NBIC inspector to have in order to perform his work correctly. Bob Farrell and Linn, place this subject on the January 2017 meeting agenda.


Attachment Page 72

5) The NBIC and ASME B&PVC Section I and VIII rules, per my review of to date, prohibit the assembly and repair of cast iron pressure vessel components and boiler parts by welding or brazing. This makes use of the cast iron welding or brazing repair methods difficult, and possibly impossible, to qualify. The reason for the prohibition is that the ASME B&PVC and the NBIC limits welded/brazed repairs to materials that have a proven history of successful repairs by use of readily available methods. Cast iron does not qualify for this approved classification because of the difficulty obtaining good welds on a repeatable basis. This has been discovered by the ASME B&PVC and NBIC as a result of past repairs and failures on cast iron pressure vessel components and boiler parts during which it was found that some repairs worked while many others failed. The only repair method for cast iron pressure vessel components I’ve found to date is in ASME B&PVC Section VIII Part UVCI-78. It allows repair by installing a single threaded pipe plug on defects of short length. In addition ASME B&PVC Section VIII Part UCI-36 (b) Openings & Reinforcements prohibits the attachment of cast iron flanges, nozzles and openings by welding or brazing. If the committee wants to approve use of welding/brazing repairs to cast iron pressure parts the members must first identify and qualify an acceptable welding or brazing method. 6) Most of the cast iron locomotive pressure parts are made from SA-48 Cast Iron or a close equivalent to it. However the ASME Section II has dropped use of the original SA-48 Cast Iron from its approved material list and has replaced it with SA-278 Gray Iron Castings For Pressure Containing Parts For Service Up To 450 Degrees F. This could make it a challenge arrange an approved repair method for the SA-48 cast iron castings. Dick


Attachment Page 73

NB15‐2210 Failed Letter Ballot Comments


Attachment Page 74

To be added to S3.5.5 Plugging of leaking or damaged tubes:

mf) As an alternative to e) any R Certificate Holder, with the concurrence of the Inspector, may install graphite tube plugs utilizing a tube plugging kit provided by an ASME Certificate Holder authorized to use the G designator. The kit shall include the following items:

1. Certified graphite plugs and certified cement ingredients, both accompanied by the appropriate documentation.

2. The qualified cementing procedure of the ASME Certificate Holder authorized to use the G designator, and a step-by-step procedural checklist that shall be followed explicitly. The procedure shall address the entire tube plugging process including plug configuration, tube hole cleaning and preparation, mixing and applying of the cement, application of the plugs, securing the plugs during the curing process, controlling the curing process, and leak testing, thereby meeting S3.3.

3. To qualify the cement technician performing the repair, aAdditional materials shall be provided and used which would allow the individual performing the installation shall use to demonstrate the ability to follow the procedure, prior to performing the repair. This repair demonstration, in conjunction with the procedural checklist, shall serve as a valid cement technician certification for a single repair operation. (what manner of evaluation represents a successful demonstration? A try-and- pull- it-apart-test, twist-test, or?)

The R Certificate Holder shall review the material certifications including verification that the shelf life of the cement has not been exceeded, and assure that the certified cement technician individual performing the repair installation has completed the qualification repair demonstration, and has access to the procedure and checklist. The Inspector shall review and verify the procedure as well as the other elements of the certified kit, as provided by the authorized G-designated ASME Certificate Holder, have been administered and completed prior to his acceptance. The R-certificate Holder shall note on the Line 8 of the R-1 Form the installation of cemented graphite tube plugs in accordance with this section.

See background information document for additional info.

Formatted: Top: 0.5"

Formatted: Strikethrough





NB15-2210 Webb Revision 11-10-16Attachment

Attachment Page 75

Background information on impregnated graphite tube plugging:

Cementing tube plugs is a proven field reliable and simple operation that has been effectively

used by graphite equipment users for over half a century. With the introduction of the G mark and part

UIG in the Code in 2010, and the subsequent inclusion of graphite pressure equipment repair

procedures to the NBIC books, the option for end users to use the procedure was obsoleted for vessels

marked with the ‘G’ mark indicator.

It is the opinion of this group that cementing plugs for tube plugging should be given some

special consideration in regards to required certifications as detailed in part UIG.

Some key points:

Cementing tube plugs is a very simple and effective operation.

All tube plugging will be performed by an “R” Certificate Holder

A cemented tube plugging operation can be performed successfully in as little as a day or two.

While there are alternative tube plugging options, cementing is far and away the most effective

and longest lasting option.

There is little to no chance of doing further damage to the part as a result of a failed tube

plugging operation. If the plug doesn’t hold, or isn’t properly installed, the resulting action is

simply back to remove the plug and install a new one in its place

In some jurisdictions, outside contractors are not allowed to perform code repairs on pressure

vessels without obtaining a state license. In actual cases like these, a user would be forced to

pull a vessel out and ship it to a repair organization certified for graphite to get the repair

completed. This can result in weeks of downtime, rather than days, for such a simple operation.

There are very few repair organizations that have graphite repair included in their scope

nationwide.

While commonly viewed as the graphite version of welding, cementing is a much less complex

operation. There is no “fusing” of material as there is in welding, where the weld filler and base

materials mix in the welded zone. A poorly cemented plug can be removed and the surrounding

material is not affected. Proper combination of ingredients to produce adequate cement,

applying enough cement to cover the joining surface, and properly curing the joint are the key

factors in a good joint. All of which will be covered in the procedure specification.

The nature of tube plugging is to simply seal a hole. This sets tube plugging apart from most

other cementing operations which can be critical to vessel fit, form, and function.

All of the design work is included in the kit. The proper bore diameter, and surface preparation

steps are detailed, the plug is pre‐made and ready to use, the cement mixing recipe is included,

and the curing procedure is also part of the given procedure.

It is our belief that tube plugging operations do need to be controlled, but think limiting them to

only repair organizations certified for graphite is unnecessary. We think that this proposal covers all the

important bases by maintaining that an ASME certificate holder authorized to use the G designator

provides the kit, a certified repair organization does the work, providing certified graphite materials with

all the proper documentation, providing a qualified cementing procedure, and by requiring that the

Inspector representing the repair organization get involved, similar to any other routine repair. All the

material is as required by the Code, and the joining methodology remains controlled by the use of the

qualified procedure.

NB15-2210 Webb Revision 11-10-16Attachment

Attachment Page 76

NB16‐0810

NBIC Part 3, Section 3, paragraph 3.4.3

EXAMPLES

OF ALTERATIONS

a) An increase in the maximum allowable working pressure (internal or external) or temperature of a

pressure‐retaining item regardless of whether or not a physical change was made to the pressure‐

retaining item;

b) A decrease in the minimum temperature;

c) The addition of new nozzles or openings in a boiler or pressure vessel except those classified as repairs;

d) A change in the dimensions or contour of a pressure‐retaining item;

e) In a boiler, an increase in the heating surface or steaming capacity as described on the original

Manufacturer’s Data Report;

f) The addition of a pressurized jacket to a pressure vessel;

g) Except as permitted in NBIC Part 3, 3.3.3 s); replacement of a pressure retaining part in a pressure

retaining item with a material of different allowable stress or nominal composition from that used in the

original design;

h) The addition of a bracket or an increase in loading on an existing bracket that affects the design of the

pressure‐retaining item to which it is attached;

i) The replacement of a pressure relieving device (PRD) as a result of work completed on a pressure‐

retaining item (PRI) that changes the resultant capacity to exceed the minimum required relieving

capacity (MRRC) required by the original code of construction as described on the original Manufacturer’s

Data Report.

j) In a Heat Recovery Steam Generator (HSRG), an increase in heat input (e.g. adjustments or modification

to a Gas Turbine which increases the exhaust energy or the addition of or an increased firing rate of duct

burners).

NB16-0810 Troutt 10-17-16Attachment

Attachment Page 77

Item Number: NB16-1302 NBIC Location: Part 3, S3.2 p)

p) Completed repairs shall be subjected to a pressure test. The test pressure shall not be less than the maximum allowable working pressure or twice the operating pressure, whichever is loweroperating pressure or more than maximum allowable working pressure. The test pressure shall be maintained for 30 minutes minimum.

Justification:

Present pressure range requirements are excessive and cause unnecessary hardship. This action brings them more in line with the general requirements in Part 3.

NB16-1302 SG Graphite Approved 7-20-16Attachment

Attachment Page 78

rferrell

Text Box

Page A-6

Item Number: NB16-1303 NBIC Location: Part 3, S3.5.1f)

f) All damage should shall be examined and should be evaluated to determine the cause. Identification

and elimination of the cause is essential in helping to prevent a recurrence

NB16-1303 SG Graphite Approved 7-20-16Attachment

Attachment Page 79

rferrell

Text Box

Page A-7

NB16‐2602 12‐21‐16 Robert V. Underwood HSB Global Standards

Purpose To define the terms “practicable” and “impracticable” throughout the NBIC Part 3.

Scope: To define the terms “practicable” and “impracticable” in the Glossary in Section 9 of the NBIC Part 3.

Background The terms “practicable” and “impracticable” are used throughout the NBIC Part 3 in relation to welding, alternative PWHT methods, alternative NDE Methods, pressure testing, and in several supplements. HSB gets many questions each year about what “practicable” means. The reply in Interpretation 98‐38 (attached) states that the determination of “practicable” is based on technical consideration of the nature and scope of the alteration activity and not a “desire to save time and/or expense.” This interpretation relates only to pressure testing and alterations. We are proposing that this definition be addressed in the Glossary in Section 9 of the NBIC Part 3.

Proposed Revision

See page 2 with proposed definition which comes from Interpretation 98‐38.

NB16-2602 Underwood 12-21-16Attachment

Attachment Page 80

Practicable ‐ The terms practicable (and impracticable) are used throughout the NBIC. The

determination of whether an activity is practicable or impracticable shall be based on technical

consideration of the nature and scope of the repair or alteration activity. The desire to save time

and/or expense does not constitute whether an activity is practicable or impracticable.

NB16-2602 Underwood 12-21-16Attachment

Attachment Page 81

National Board of Boiler and Pressure Vessel Inspectors National Board Inspection Code

Submission of Public Review Comment 2017 Draft Edition

Comments Must be Received No Later Than: October 10, 2016

Instructions: If unable to submit electronically, please print this form and fax or mail. Print or type clearly.

Date: Commenter Name: Commenter Address: Commenter Phone: Commenter Fax: Commenter Email: Section/Subsection Referenced: Comment/Recommendation: Proposed Solution: � New Text � Revise Text � Delete Text

Source: � Own Experience/Idea � Other Source/Article/Code/Standard Submit Form To: Bradley Besserman, NBIC Secretary, The National Board of Boiler & Pressure

Vessel Inspectors, 1055 Crupper Avenue, Columbus, OH 43229, email: [email protected]

PLEASE SUBMIT ONLY ONE COMMENT/RECOMMENDATION PER PAGE Make additional copies as needed

NB Use Only

Commenter No. Issued: Project Committee Referred To:

Comment No. Issued:

9/9/16

Robert Price243 Lincoln Ave.

Mt. Holly, NJ 08060(609) 841-5093

N/A

[email protected] below

1. Add mechanical Repair and example to NBIC Part 3 Scope, 1.1, Scope of Work 1.6.1 c),3.3.2, Routine Repair, 3.3.3, Examples of Repairs, 3.3.4.4-a) add example of MechanicalTube replacement in water tube, fire tube boilers or heat exchangers.

2. Add check-box to the NB forms R-1 and R-2. Mechanical repairs, i. e. rolling tubeswithout welding or replacement of threaded piping as defined in ASME Section 1PG-112.3.5 classified as P-4b piping.

ASME Sections I, IV, VIII div. 1

NB16-2901 Price 10-28-16Attachment

Attachment Page 82

NB16-3001 Kincs 10-28-16Attachment

Attachment Page 83

NB16-3002 Kincs 10-28-16Attachment

Attachment Page 84

Question: In NBIC Part 2, Sec. 2.5.7, g), does the phrase “organization accredited by the National Board” include a VR Certificate Holder? Proposed Answer: Yes. Background: NBIC, Part 2, Sec. 2.5.7, g) If a pressure test indicates the valve does not open within the requirements of the original code of construction, but otherwise is in acceptable condition, minor adjustments (defined as no more than twice the permitted set pressure tolerance) shall be made by an organization accredited by the National Board to reset the valve to the correct opening pressure. All adjustments shall be resealed with a seal identifying the responsible organization and a tag shall be installed identifying the organization and the date of the adjustment.

IN16-0901 Cox 10-19-16Attachment

Attachment Page 85

NB15-1203/NB16-0603 7/18/16 SUPPLEMENT 9 PROCEDURES FOR REPAIRS OF NUCLEAR SAFETY RELATED PRESSURE RELIEF DEVICES S9.1 INTRODUCTION Nuclear safety related pressure relief valves and power operated pressure relief valves may be repaired provided the requirements of this supplement are met. These rules classify nuclear safety related pressure relief valves into three groups based upon the original code of construction and capacity certification status. Group 1: ASME Section I and Section VIII pressure relief valves (including power operated pressure relief valves) used in nuclear safety related service with National Board capacity certification. Group 2: Section III NV stamped Class 1, 2, or 3 pressure relief valves (including power operated pressure relief valves) with National Board capacity certification. Group 3: ASME Section VIII and Section III Class 1, 2, or 3 pressure relief valves (including power operated pressure relief valves) without National Board capacity certification used in nuclear safety related service. This group shall also apply ot pressure relief valves constructed to codes or Standards other than ASME (see NBIC Part 3, Category 3). The terms “pressure relief valves” and “pressure relief devices” are used interchangeably, and both include power operated pressure relief valves. Replacement of rupture disks in rupture disk holders or in systems by mechanical means is not considered a repair activity under the scope of this supplement. The rules of this supplement may be used for other than nuclear safety device applications. S9.2 ADMINISTRATIVE PROCEDURES a) The repair organization shall obtain a “VR” Certificate of Authorization and stamp. b) The repair organization shall obtain a National Board “NR” Certificate of Authorization and stamp. The requirements for said certificate and stamp include, but are not limited to, the following. The repair organization shall: 1) Maintain a documented quality assurance program that meets the applicable requirements of NBIC Part 3, 1.8. This program shall also include all the applicable requirements for the use of the “VR” stamp; 2) Have a contract or agreement with an Inspection Agency to provide inspection of repaired nuclear pressure relief devices by Inspectors who have been qualified in accordance with the requirements of ASME QAI-1, Qualifications for Authorized Inspection; 3) Successfully complete a survey of the quality assurance program and its implementation. This survey shall be conducted by representatives of the National Board, the Jurisdiction wherein the applicant’s repair facilities are located, and the applicant’s Authorized Inspection Agency. Further verification of such implementation by the survey team may not be necessary if the applicant holds a valid ASME “NV” certificate and can verify by documentation the capability of implementing the quality assurance program for repair of “NV”-stamped pressure relief devices, covered by the applicant’s ASME “NV” certificate.

Deleted: TO EXTEND THE “VR” CERTIFICATE OF AUTHORIZATION AND STAMP TO ASME “NV” STAMPED PRESSURE RELIEF DEVICES

Deleted: Approval to extend the scope of the National Board “VR” Certificate of Authorization to the Certificate Holder to use the “VR” Stamp on ASME Code “NV” Class 1, 2, or 3 stamped pressure relief devices, which have been capacity certified by the National Board, may be given subject to the provisions that follow.

Comment [AC1]: WhatisaNuclearSafetyDevice?PressurerelievingsafetydeviceismentionedinNB,NC,ND.QuickAccessandLockingSafetyDeviceismentionedinNE-3327.2(Ithinkitdoesnotapply)

Deleted: hold

Deleted: valid

Comment [AC2]: Unnecessarywords.

Comment [AC3]: SafetyRelatedPRVsinBalanceofPlantServiceataNuclearPowerStationmaybeASMESecVIII,butaretheyactuallynuclearPRD?Ithinknot.

Deleted: “NV”-stamped

NB16-0603 Cox Suggestions 11-3-16Attachment

Attachment Page 86

c) The application of the “NR” Certificate of Authorization and stamp shall clearly define the scope of intended activities with respect to the repair of nuclear pressure relief devices. d) Revisions to the quality assurance program shall be acceptable to the Authorized Nuclear Inspector Supervisor and the National Board before being implemented. e) The scope of the “VR” Certificate of Authorization shall include repair of nuclear pressure relief devices (denoted on the VR Certificate as Section III). f) Verification testing of valves repaired by the applicant shall not be required provided such testing has been successfully completed under the applicant’s “VR” certification program for the applicable test fluids. g) A survey of the applicant for the “VR” Certificate of Authorization and endorsement of the repair of nuclear pressure relief devices may be made concurrently. S9.3 GENERAL RULES a) Group 1 and Group 2 pressure relief devices which have been repaired in accordance with these rules, shall be stamped with both the “VR” and “NR” stamps. They shall be classified as either NR Category 1 or Category 2 as applicable. Group 3 pressure relief devices which have been repaired in accordance with these rules shall be stamped with the “NR” stamp. They shall be classified as either NR Category 2 or Category 3 as applicable. b) The “VR” and “NR” stamps shall be applied only to nuclear safety related pressure relief devices that have been disassembled, inspected, and repaired as necessary, such that the valves’ condition and performance are equivalent to the standards for new valves. c) All measuring and test equipment used in the repair of pressure relief devices shall be calibrated against certified equipment having known valid relationships to nationally recognized standards. d) Documentation of the repair of nuclear safety related pressure relief devices shall be recorded on the National Board Form NVR-1, Report of Repair/ Replacement Activities for Nuclear Pressure Relief Devices, in accordance with the requirements of NBIC Part 3, 1.8. The original code of construction and capacity certification status shall be identified on the NVR-1 form. e) When an ASME “NV”-stamped pressure relief device requires a duplicate nameplate because the original nameplate is illegible or missing, it may be applied using the procedures of NBIC Part 3, 5.12.5 provided concurrence is obtained from the Authorized Nuclear Inspector and Jurisdiction. In this case the nameplate shall be marked “SEC I”, “SEC. III”, or “SEC VIII” to indicate original ASME Code stamping. f) Repair activities for pressure relief devices shall not include rerating of the device. Set pressure

changes within the range of the valve manufacturer’s capacity certification and the design pressure of the valve (see Part 3, 5.12.3) are permitted, provided the new set pressure and capacity rating are technically justified and documented for the design of the system where the device will be used. Set pressure changes are not considered to be rerating. Set pressure changes shall not be performed on Group 3 pressure relief devices.

g) Conversions of pressure relief devices as described in NBIC Part 3, S7.2 b) are permitted as part of

repair activities. h) Set pressure changes or conversions of pressure relief devices shall be described in the “Remarks”

section of Form NVR-1.

Deleted: Section III, “NV”-stamped

Comment [AC4]: Samecomment,SecVIIIPRDsinBOPServicer,evenwhensafetyrelated,arenotnecessarilynuclearjustbecausetheyareinanuclearfacility


Comment [AC5]: Whynotsaysafetyrelatedratherthan“nuclear?”

Comment [AC6]: HowaretheygoingtocompleteverificationtestingwithouthacingdoneitundertheVRProgram?IthoughtthatwasthewholeideaoftheNR/VRCertificate?


Comment [AC7]: Sameissue,Safetyrelateddoesnotequalnuclear

Deleted: ASME Code Section III, “NV”-stamped pressure relief devices,

Deleted: “NV” stamped (Class 1, 2, or 3) National Board capacity certified

Comment [AC8]: Thistermisusedoncein13SectionsASMErelatedtoNuclear.SecIII-A,W-2250[9]regardingcoatings.WheredoesthistermapplytoNR/VR?


Deleted: a

NB16-0603 Cox Suggestions 11-3-16Attachment

Attachment Page 87


Attachment Page 88









NB Use Only


Comment No. Issued:

09/23/2016J. Alton Cox

213 Park View Dr.Belmont, NC 28012

704-301-8532704-820-8408

[email protected]¶ 3.2.5.2

In the last sentence of the proposed ¶ 3.2.5.2 VALVE ADJUSTMENTS, the In-Service TestOnly Organizations (T/O), as referenced in proposed ¶ 4.1 of Part 4, "T/O" — In-ServiceTesting Only of Pressure Relief Valves, should be added after "VR" Certificate Holders. ThisT/O option was added by the National Board in July 2016, and therefore not a part of theexisting draft.

NB16-3101 Cox 10-28-16Attachment

Attachment Page 89









NB Use Only


Comment No. Issued:

09/23/2016J. Alton Cox

213 Park View Dr.Belmont, NC 28012

704-301-8532704-820-8408

[email protected]¶ 4.2.1 a)2), 4.7.5, 4.8.5.4 d)1)a.

The above referenced paragraphs do not acknowledge recent changes to ASME markingrequirements. The new ASME Certification Mark carries a specific designator to replace theformer Code Symbols. The existing wording should be replaced with the following:

“... with the ASME Certification Mark with the “V,” “HV,” “UV,” or “NV” Designator or thesupplanted “V,” “HV,” “UV,” or “NV” Code Symbol ...”

This will allow “VR” Certificate Holders to repair PRVs manufactured prior to the 2014ASME Certification Mark issuance, as well as more recently manufactured PRVs.

NB16-3102 Cox 10-28-16Attachment

Attachment Page 90









NB Use Only


Comment No. Issued:

2016-10-06

Bernd JörgensenLESER GmbH & Co.KG

20506 Hamburg, P.O.B 261651; Germany+49 (0) 40 25165 158

+49 (0) 40 25165 558

[email protected]. 2.9.1 Valve Requirements- General

a) Only direct spring loaded safety valves with or without supplementary loading system,direct spring loaded safety relief valves with or without supplelemtary loading system, orpilot operated pressure relief valves designed to relieve steam steam shall be used forsteam service.

Rational: Supplementary Loading systems for safety (relief) valves are well known in thesteam boiler market defined by internationl standards and are world wide available.

NB16-3201 Jorgensen 10-28-16Attachment

Attachment Page 91

Item Number: NB16-0801 NBIC Location: Part 1 No Attachment

General Description: Is it standard operating procedure (per NBIC) to do hydrostatic pressure tests on installed ASME Section IV boilers at 150% of the rated pressure as part of the installation inspection?

Question: If a pressure test has been performed and documented on the applicable Manufacturer’s Data Report for a boiler, pressure vessel or piping, is an additional pressure test required prior to initial operation? Reply: NO

‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐



Inquiry: IN16-0701

Source: NB16-0801

Subject: Pressure Testing - Part 1

Edition: 2015 NBIC

Question 1: Is it standard operating procedure (per NBIC) to do hydrostatic pressure tests on installed ASME Section IV boilers at 150% of the rated pressure as part of the installation inspection?

Reply 1:

Committee’s Question:

If a pressure test has been performed and documented on the applicable Manufacturer’s Data Report for a boiler, pressure vessel or piping, is an additional pressure test required prior to initial operation?

Committee’s Reply:

No

Rationale: 2.10.2 Power Boilers, 3.10.1 Heating Boilers, 4.6 Pressure Vessels, 5.4 Piping It is not the intent of the code to mandate post construction testing at 150% of the rated pressure.

SC Vote Passed – Unanimous

NBIC Vote

IN16-0701 SC Installation 7-21-16Attachment

Attachment Page 92

2.10.2 PRESSURE TEST Prior to initial operation, the completed boiler, including pressure piping, water columns, superheaters, economizers, stop valves, etc., shall be pressure tested in accordance with the original code of construction. Any pressure piping and fittings such as water columns, blowoff valves, feedwater regulators, superheaters, economizers, stop valves, etc., which are shipped connected to the boiler as a unit, shall be hydrostatically tested with the boiler and witnessed by an Inspector. 3.10.1 PRESSURE TEST Prior to initial operation, the completed boiler, individual module, or assembled module, shall be subjected to a pressure test in accordance with the requirements of the original code of construction. 4.6 TESTING AND ACCEPTANCE a) The installer shall exercise care during installation to prevent loose weld material, welding rods, small tools, and miscellaneous scrap metal from getting into the vessel. The installer shall inspect the interior of the vessel and its appurtenances where possible prior to making the final closures for the presence of foreign debris. b) The completed pressure vessel shall be pressure tested in the shop or in the field in accordance with the original code of construction. When required by the Jurisdiction, owner or user, the Inspector shall witness the pressure test of the completed installation, including piping to the pressure gage, pressure relief device, and, if present, level control devices. 5.4 EXAMINATION, INSPECTION, AND TESTING The owner shall ensure that all examinations, inspections, and tests required by the code of construction have been performed prior to operation.

IN16-0701 SC Installation 7-21-16Attachment

Attachment Page 93


Attachment Page 94

NB16-0102- Letter Ballot At this time, I will vote to “disapprove” this item. My understanding of this action item was to; generally consolidate the pressure testing requirements of the various Part 1, Sections into a more general practice to be described in Part 1, Section 1-General Guidelines. In my read whether intended or my misunderstanding, the product of the SC-Installation effort may have offered the ASME code-required pressure testing to be circumvented as presented in the SC-proposed paragraph “b)”. To add, I would propose for consideration the item as presented here or otherwise presented be inserted as: Part 1, Section 1, 1.4.1 b) with the current 1.4.1 b) re-introduced to become 1.4.1 c). As a note: the text in red represents the text implying the operational test may satisfy final acceptance of the unit. –M. Webb, 10-5-16 Background: The action proposed is to generally describe and merge the pressure test and acceptance requirements found in Part 1, 2.10.2, 2.10.4, 3.10.1, 4.6, and 4.7.6 into a general topic found in Part 1, Section 1, Installation General Guidelines 1.4 CERTIFICATION, INSPECTION, AND JURISDICTIONAL REQUIREMENTS 1.4.1 RESPONSIBILITY Note: Any proposed revision to the language presented by SC-Installation is double underlined- A “NEW” 1.4.1 b)

1.4.1 b) EXAMINATION, TESTING, AND ACCEPTANCE

1) The installer shall exercise care during installation to prevent foreign debris not limited to, loose weld material, welding rods, small tools, and miscellaneous scrap metal from getting into the boiler, pressure vessel, adjacent system equipment or piping as applicable. The installer shall examine inspect the interior of the vessel aforementioned equipment and its appurtenances where possible prior to making the final equipment closures, all the while assuring for the presence absence of this foreign debris.

2) The completed boiler, pressure vessel, or adjacent piping, as applicable shall be pressure

tested in the shop or in the field in accordance with the original code of construction. When required by the jurisdiction prior to final acceptance, an operational test shall be performed on any components whose who’s pressure test is not documented under on the items’ item’s Manufacturer’s Data Report, when required. This test should be at a pressure not to exceed the lowest pressure relief device set-point, and shall be aligned with the equipment Manufacturer’s operating guidance, system-operating procedures and required controls. The test data shall be recorded and the data made available as required. This operational test may be used as the final acceptance of the unit; if allowed by the jurisdiction.

1.4.1 c) The current 1.4.1 b) (NBIC Part 1, 2015-edition) now becomes 1.4.1 c) in its entirety

NB16-0102 Webb Suggestions 11-3-16Attachment

Attachment Page 95

Action Item Request Form

12/1/2016

Request for Code revision:

a) Proposed Revisions or Additions

Existing Text: NBIC PART 1 2015

b) Statement of Need

b) Provide a brief explanation of the need for the revision or addition.

In the figure 3.7.5.2‐b there are no stop valves shown on the supply and return piping as is stated in paragraph 3.7.5.2.

NB16-0903 Vallance 12-1-16Attachment

Attachment Page 96

c) Background Information

The valves are shown in figure 3.7.5.2‐a

d) Consider adding the valves to the supply and return to figure 3.7.5.2‐b as stated in paragraph 3.7.5.2

William Vallance Senior Staff Engineer The National Board 614 888 8320 ext. 409


Attachment Page 97


12/8/2016



Existing Text: NBIC PART 1 2017 Approved Draft


c) Background Information

To be able to explain this term to perspective IS commissioned inspectors or owner/users would be difficult if we were

to assume its meaning without code wording.

d) I would suggest stating in each paragraph what heaters the text is for such as, potable water heater, superheater, or

thermal fluid heaters.


In the 2017 General Requirements the term is used “heater” in various paragraphs when there is no explanation of what type of heater this term is for.


Attachment Page 98


12/8/2016



Existing Text: NBIC PART 1 2017 Approved Draft


c) I would suggest the following:

Two means of exit shall be provided for equipment rooms exceeding 500 sq. ft. (46.5 sq. m) of floor area and containing one or more boilers and or potable water heaters having a combined fuel capacity of 1,000,000 Btu/hr (293 kW) or more (or equivalent electrical heat input). Each elevation shall be provided with at least two means of exit, each to be remotely located from each other. A platform at top of a single boiler, heater, and vessel is not considered an elevation. .


1.6.3 Two means of exit shall be provided for equipment rooms exceeding 500 sq. ft. (46.5 sq. m) of floor area and containing one or more boilers having a combined fuel capacity of 1,000,000 Btu/hr (293 kW) or more (or equivalent electrical heat input). Each elevation shall be provided with at least two means of exit, each to be remotely located from each other. A platform at top of a single boiler, heater, vessel is not considered an elevation.

Need is to bring a fired appliance such as a potable water heater into the combined fuel capacity for the equipment room.


Attachment Page 99









NB Use Only


Comment No. Issued:

September 19, 2016

Brian W. MooreHartford Steam Boiler, One State Street

P.O. Box 5024, Hartford, CT 06102-5024860-722-5657

860-722-5530

[email protected] 1 Section 1.6.1

Including the phrase "manufacturer’s recommendations, and/or other industry standards, asapplicable" is scope creep and beyond the knowledge and training of boiler inspectors.Structure standards should not be directly or indirectly made part of the "requirements" inPart 1. An in-service inspector has no way of verifying the requirements of otherunspecified standards.

Delete the phrase noted above.

NB16-2801 Moore 10-28-16/PR16-0401 9-26-16Attachment

Attachment Page 100









NB Use Only


Comment No. Issued:

September 19, 2016



860-722-5530

[email protected] 1 Section 1.6.2 a

Including subparagraph b) "manufacturer’s recommendations, and/or other industrystandards, as applicable" is scope creep and beyond the knowledge and training of boilerinspectors. Structure standards should not be directly or indirectly made part of the"requirements" in Part 1.

Delete the phrase noted above.


Attachment Page 101









NB Use Only


Comment No. Issued:

September 19, 2016



860-722-5530

[email protected] 1 Section 1.6.5a

Including the phrase "manufacturer’s recommendations, and/or other industry standards, asapplicable" is scope creep and beyond the knowledge and training of boiler inspectors.Structure standards should not be directly or indirectly made part of the "requirements" inPart 1. An in-service inspector has no way of verifying the requirements of otherunspecified standards, such as Building Codes, Mechanical Codes, Fire Codes, or ElectricalCodes.

Delete the phrase ", and/or other industry standards, as applicable" .


Attachment Page 102









NB Use Only


Comment No. Issued:

September 19, 2016



860-722-5530


See attached comments.


Attachment Page 103

Part 1 Section 1.6.8

The proposed subparagraph 1.6.8 directly contradicts subparagraph 1.4.1 with regard to "environmental requirements".

Subparagraph 1.6.8 reads: "Chimneys or stacks shall be installed in accordance with jurisdictional and environmental requirements, manufacturer’s recommendations, and/or industry standards, as applicable."

Subparagraph 1.4.1 reads: "Unless otherwise specifically required by the Jurisdiction, the duties of the inservice inspector do not include the installation’s compliance to other standards and requirements (e.g., environmental..."

Delete reference to "environmental requirements" ================================================== Also delete the phrase ", and/or industry standards, as applicable."

Including the phrase "manufacturer’s recommendations, and/or other industry standards, as applicable" is scope creep and beyond the knowledge and training of boiler inspectors. Structure standards should not be directly or indirectly made part of the "requirements" in Part 1. An in-service inspector has no way of verifying the requirements of other unspecified standards, such as Building Codes, Mechanical Codes, Fire Codes, or Electrical Codes.


Attachment Page 104









NB Use Only


Comment No. Issued:

September 19, 2016



860-722-5530


The proposed subparagraph 1.6.5 directly contradicts subparagraph 1.4.1 with regard to"environmental requirements".

Subparagraph 1.6.5 reads: " All fuel systems shall be installed in accordance withjurisdictional and environmental requirements, manufacturer’s recommendations, and/orindustry standards, as applicable."

Subparagraph 1.4.1 reads: "Unless otherwise specifically required by the Jurisdiction,the duties of the inservice inspector do not include the installation’s compliance to otherstandards and requirements (e.g., environmental..."

Delete reference to "environmental requirements"


Attachment Page 105









NB Use Only


Comment No. Issued:

September 19, 2016



860-722-5530


See attached comments.


Attachment Page 106

Part 1 Section 1.6.8

The proposed subparagraph 1.6.8 directly contradicts subparagraph 1.4.1 with regard to "environmental requirements".

Subparagraph 1.6.8 reads: "Chimneys or stacks shall be installed in accordance with jurisdictional and environmental requirements, manufacturer’s recommendations, and/or industry standards, as applicable."

Subparagraph 1.4.1 reads: "Unless otherwise specifically required by the Jurisdiction, the duties of the inservice inspector do not include the installation’s compliance to other standards and requirements (e.g., environmental..."

Delete reference to "environmental requirements" ================================================== Also delete the phrase ", and/or industry standards, as applicable."

Including the phrase "manufacturer’s recommendations, and/or other industry standards, as applicable" is scope creep and beyond the knowledge and training of boiler inspectors. Structure standards should not be directly or indirectly made part of the "requirements" in Part 1. An in-service inspector has no way of verifying the requirements of other unspecified standards, such as Building Codes, Mechanical Codes, Fire Codes, or Electrical Codes.


Attachment Page 107









NB Use Only


Comment No. Issued:

September 19, 2016



860-722-5530

[email protected] 1 Part 1, Supplement 6.2

The proposed subparagraph S6.2 directly contradicts subparagraph 1.4.1 with regard to"environmental requirements".

S6.2 reads: The allowable operating parameters of the combustion air intake and theexhaust gas venting shall be in accordance with jurisdictional, environmental andmanufacturers recommendations, as applicable

Subparagraph 1.4.1 reads: "Unless otherwise specifically required by the Jurisdiction,the duties of the inservice inspector do not include the installation’s compliance to otherstandards and requirements (e.g., environmental..."

Delete reference to "environmental requirements"


Attachment Page 108









NB Use Only


Comment No. Issued:

September 19, 2016



860-722-5530

[email protected] 1 Section 2.5.3.2

In place of the deleted text in subparagraph d) add the following:

d) Remote emergency shutdown switches shall not be retroactively installed.

Rationale: In my experience, the electricians who retroactively install such switches do notunderstand boiler safety limit controls. Too many claims and near misses occur when acontrol is retroactively installed by unqualified individuals. In addition, tapping into thecontrols on some older boilers could even be hazardous since the controls were probablynot designed to handle that circuit. Such switches should only be addresssed in newinstallations.

NB16-2803 Moore 10-28-16Attachment

Attachment Page 109









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Comment No. Issued:

September 19, 2016



860-722-5530

[email protected] 1 Section 2.7.5 p)

NB-23 NBIC is an ANSI accredited consensus standard. However, NB-27 is not. I do notthink this paragraph meets ANSI Essential Requirements by making the paragraphmandatory. There has been no public review or comment on NB-27.

Change text as follows to meet ANSI Essential Requriements:p) Boiler blowoff systems may be constructed as recommended in the Guide for BlowoffVessels (NB-27), which can be found on the National Board website,www.nationalboard.org.


Attachment Page 110









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Comment No. Issued:

September 19, 2016



860-722-5530

[email protected] 1 Section 3.8.1.5

Change "water" to "fluid" in "...a) Each automatically fired steam or vapor-system boiler shallhave an automatic low-water fuel cutoff so located as to automatically cut off the fuel supplywhen the surface of the water falls to..."

Delete: "...or vapor-system..."

Rationale: This is the only location within this paragrpah that uses this term "vapor-systemboiler". Including thermal fluid heaters, other types of vaporizing boilers contain a fluid otherthan water.See also Comment Part 1, 2.8.5.


Attachment Page 111









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Comment No. Issued:

September 19, 2016



860-722-5530

[email protected] 1 Part 1, Supplement 6.1b)

"b) This supplement is based on Local, State or National Building Codes requiring theinstallation of a Carbon Monoxide (CO) detector/alarm in the boiler room."

Delete this text.

Rationale: Building Codes, Mechanical Codes, Electric Codes, etc are beyond theknowledge and training of in-service boiler inspectors and are the providence of buildingofficials. This is scope creep beyond what in-service boiler inspectors should beresponsible.


Attachment Page 112









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Comment No. Issued:

September 19, 2016



860-722-5530

[email protected] 1 Part 1, Supplement 6.4

The entire S6.4 addresses requirements that represent scope creep beyond the knowledgeand training of in-service boiler inspectors. The information is, however, good guidance forinstallers and owners. In-service inspectors have no way judge the adequacy of S6.4provisions.

Rewrite the section to make it clear to jurisdictional authorities that the section is theresponsibility of the owner and installer.

See attached suggestion.


Attachment Page 113

Part 1 S6.4 FLUE GAS VENTING SYSTEM PIPING REQUIREMENTSRECOMMENDATIONS

ea) This supplement requires recommends that the owner/user/installer contact the authority having Jurisdiction jurisdiction regarding the installation of carbon monoxide (CO) detector/alarm in boiler rooms in which condensing boilers are to be installed

ab) The vent piping shall should be corrosion resistant and fabricated from either stainless alloy or plastic material as defined by the boiler manufacturer and certified for the application.

bc) The diameter of the vent piping shall should be as defined by the boiler manufacturer and shall should not be reduced, except as allowed by the boiler manufacturer.

cd) The “Total Equivalent Length” of the vent piping, and the pressure drop through the vent piping, shallshould not exceed that stated in the Boiler Manufacturer’s Installation Manual. (Note: Equivalent Length includes the pressure loss effect of various pipe fittings, such as elbows, etc.) Horizontal pipe runs shall should slope toward the boiler and the condensate collection point.

de) The termination point of the vent piping shall should be positioned such that there is no possibility of vented flue gas being entrained in the combustion air intake, as defined by the manufacturer and National Fuel Gas Code (ANSI Z223.1). Additionally the vent termination shall should be located above the highest known snowline for the location involved, and be designed in such a manner, so as to prevent freezing.

e) This supplement requires the owner/user/installer contact the authority having Jurisdiction regarding the installation of carbon monoxide (CO) detector/alarm in boiler rooms in which condensing boilers are to be installed.


Attachment Page 114



Inquiry: IN16‐0501

Source: Chris Heichel

Subject: Change of service – LPG & ammonia

Edition: 2015 NBIC

Question 1: Can pressure vessels that were previously used in anhydrous ammonia service be converted to LPG service?

Reply 1: No, except for the following:

ASME containers of 3000 gal (11.4 m3) water

capacity or less used to store anhydrous ammonia,

except for containers used in cargo tank vehicle

service, shall not be converted to LP‐Gas service.

The above paragraph is proposed to be included in

the 2017 NBIC (Part 2, S7.8.6)

SC Vote Passed – Unanimous

NBIC Vote

IN16-0501 SC Inspection 7-20-16Attachment

Attachment Page 115



Comments Must be Received No Later Than: October 10, 2016 Instructions: If unable to submit electronically, please print this form and fax or mail. Print or type clearly. Date: Commenter Name: Commenter Address: Commenter Phone: Commenter Fax: Commenter Email: Section/Subsection Referenced: Comment/Recommendation: Proposed Solution: □ New Text □ Revise Text □ Delete Text

Source: □ Own Experience/Idea □ Other Source/Article/Code/Standard Submit Form To: Bradley Besserman, NBIC Secretary, The National Board of Boiler & Pressure



NB Use Only


Comment No. Issued:

NB16-2808 Moore 10-28-16/Part 2 Section 2.3.6.6c1-2Attachment

Attachment Page 116







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Comment No. Issued:

NB16-2808 Moore 10-28-16/Part 2 Section 2.3.6.6dAttachment

Attachment Page 117

Part 2 Section 2.3.6.6 d) Any damage to the cylinder or closures can lead to premature failure. Frequent visual inspection should be made of internal and external surfaces of the cylinder, frame and closures. A thorough examination should be completed if any visually apparent damage is identified or if any excursion beyond design temperature or pressure occurs. In addition, surfaces of the cylinder and closures should be examined by dye penetrant or magnetic particle method at intervals based on vessel remaining life. Closures may require ultrasonic examination of passageways. As part of this inspection guideline for wire wound pressure vessels, frequent inspection, the following items should be reviewed:

1) Verify no change in the process, such as theChanges of the processing fluid, that might adversely impact vessel integrity.

2) Review the vessel manufacturer’sManufacture's inspection recommendations for vessel, closuresclosures, and frame are important. If manufacturer’s recommendations are not available, the owner should obtain recommendations from a recognized wire wound vessel service provider.

3) Verify any repairRepairs to pressure retaining items has beenshould be completed by a National Board authorized service provider having wire wound vessel expertise.

4) Verify overpressureOverpressure protection with appropriate set pressure and capacity is should be provided. Rupture discs are commonly used for pressures exceeding 14,500 psi (100 MPa) to avoid valve seat leakage. Overpressure protection devices are frequently replaced to avoid premature operation.

5) If there are no manufacturer’s recommendations available for the vessel, the following are additional recommended inspections that should be conducted to ensure vessel integrity and safety.

a. Conduct annualAnnual visual and dimensional vessel inspections with should be conducted using liquid penetrant examination of maximum stressed areas to ensure that the surfaces are free of defects. Conduct ultrasonicUltrasonic examination of the vessel should be conducted after every 25% of the design cycle life or every five years, whichever comes first, to detect subsurface cracks. Special attention should be given to the roots of threads and closures using threaded head retention construction. Other geometric discontinuities that are inherent in the design or irregularities resulting from localized corrosion, erosion, or mechanical damage should be carefully examined. This is particularly important for units of monoblock construction.


Attachment Page 118

b. The closure mechanism of the vessel end-closure is may be opened and closed frequently during operation. It The closure mechanism should be closely inspected for freedom of movement and proper contact with its locking elements. Wire wound vessels must have yokeThe presences of yolk-type closures should be verified so the yoke frame will need to beand should be closely inspected on a regular basis

6) Gages, Safety Devices, and Controls

a. Verify that theThe vessel is should be provided with control and monitoring of pressure, temperature, the electrical system, fluid flow, liquid levels, and all variables that are essential for the safe operation of the system. If the vessel is automatically controlled, manual override should be available. Also, safety interlocks should be provided on the vessel closure to prevent vessel pressurization if the vessel closure is not complete and locked.

b. Verify that allAll safety device isolation valves are should be locked open if used.

c. Verify appropriateAppropriate pressure relief devices is should be installed with the setpoint at the lowest pressure possible, consistent with the normal operating pressure, but in no case higher than the design operating pressure of the vessel. Rupture discs are normally considered more suitable for these types of applications, since pressure relief devices operating at pressures above 14,500 psi may tend to leak by their seat.

d. Verify that pressurePressure and temperature of the vessel coolant and vessel wall is should be controlled and monitored. Interlock devices should be installed that will de-energize or depressurize the vessel at established setpoints.

e. Verify audibleAudible and visual alarms are should be installed to indicate unsafe conditions.


Attachment Page 119







NB Use Only


Comment No. Issued:

NB16-2808 Moore 10-28-16/Part 2 Section 2.3.6.6d-2Attachment

Attachment Page 120

Part 2 Section 2.3.6.6 d) Any damage to the cylinder or closures can lead to premature failure. Frequent visual inspection should be made of internal and external surfaces of the cylinder, frame and closures. A thorough examination should be completed if any visually apparent damage is identified or if any excursion beyond design temperature or pressure occurs. In addition, surfaces of the cylinder and closures should be examined by dye penetrant or magnetic particle method at intervals based on vessel remaining life. Closures may require ultrasonic examination of passageways. As part of this inspection guideline for wire wound pressure vessels, frequent inspection, the following items should be reviewed:

1) Verify no change in the process, such as theChanges of the processing fluid, that might adversely impact vessel integrity.

2) Review the vessel manufacturer’sManufacture's inspection recommendations for vessel, closuresclosures, and frame are important. If manufacturer’s recommendations are not available, the owner should obtain recommendations from a recognized wire wound vessel service provider.

3) Verify any repairRepairs to pressure retaining items has beenshould be completed by a National Board authorized service provider having wire wound vessel expertise.

4) Verify overpressureOverpressure protection with appropriate set pressure and capacity is should be provided. Rupture discs are commonly used for pressures exceeding 14,500 psi (100 MPa) to avoid valve seat leakage. Overpressure protection devices are frequently replaced to avoid premature operation.

5) If there are no manufacturer’s recommendations available for the vessel, the following are additional recommended inspections that should be conducted to ensure vessel integrity and safety.

a. Conduct annualAnnual visual and dimensional vessel inspections with should be conducted using liquid penetrant examination of maximum stressed areas to ensure that the surfaces are free of defects. Conduct ultrasonicUltrasonic examination of the vessel should be conducted after every 25% of the design cycle life or every five years, whichever comes first, to detect subsurface cracks. Special attention should be given to the roots of threads and closures using threaded head retention construction. Other geometric discontinuities that are inherent in the design or irregularities resulting from localized corrosion, erosion, or mechanical damage should be carefully examined. This is particularly important for units of monoblock construction.


Attachment Page 121

b. The closure mechanism of the vessel end-closure is may be opened and closed frequently during operation. It The closure mechanism should be closely inspected for freedom of movement and proper contact with its locking elements. Wire wound vessels must have yokeThe presences of yolk-type closures should be verified so the yoke frame will need to beand should be closely inspected on a regular basis

6) Gages, Safety Devices, and Controls

a. Verify that theThe vessel is should be provided with control and monitoring of pressure, temperature, the electrical system, fluid flow, liquid levels, and all variables that are essential for the safe operation of the system. If the vessel is automatically controlled, manual override should be available. Also, safety interlocks should be provided on the vessel closure to prevent vessel pressurization if the vessel closure is not complete and locked.

b. Verify that allAll safety device isolation valves are should be locked open if used.

c. Verify appropriateAppropriate pressure relief devices is should be installed with the setpoint at the lowest pressure possible, consistent with the normal operating pressure, but in no case higher than the design operating pressure of the vessel. Rupture discs are normally considered more suitable for these types of applications, since pressure relief devices operating at pressures above 14,500 psi may tend to leak by their seat.

d. Verify that pressurePressure and temperature of the vessel coolant and vessel wall is should be controlled and monitored. Interlock devices should be installed that will de-energize or depressurize the vessel at established setpoints.

e. Verify audibleAudible and visual alarms are should be installed to indicate unsafe conditions.


Attachment Page 122







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Comment No. Issued:

NB16-2808 Moore 10-28-16/Part 2 Section 2.3.6.9Attachment

Attachment Page 123







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Comment No. Issued:

NB16-2809 Moore 10-28-16/Part 2 S12.2dAttachment

Attachment Page 124

n1201127

Line

n1201127

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Comment No. Issued:

NB16-2809 Moore 10-28-16/Part 2 Supplement 12Attachment

Attachment Page 125

Part 2 Supplement 12 Replace mandatory "shall" with nonmandatory "should" in all places listed below. S12.3 b) Portable LCDSV installations with no permanent remote fill connection: Warning: LCDSVs shall should not be filled indoors… 4) Are provided with a pathway that provides a smooth rolling surface to the outdoor, unenclosed fill area. There shall should not be any stairs or other than minimal inclines in the pathway. S12.5 A continuous gas detection system shall should be provided in the room or area where container systems are filled and used, in areas where the heavier that air gas can congregate and in below grade outdoor locations. Carbon dioxide (CO2) sensors shall should be provided within 12 inches (305mm) of the floor in the area where the gas is most likely to accumulate or leaks are most likely to occur. The system shall should be designed to detect and notify at a low level alarm and high level alarm. a) The threshold for activation of the low level alarm shall should not exceed a carbon

dioxide concentration of 5,000 ppm (9,000 mg/m3) Time Weighted Average (TWA) over 8 hours. When carbon dioxide is detected at the low level alarm, the system shall should activate a signal at a normally attended location within the building.

b) The threshold for activation of the high level alarm shall should not exceed a carbon dioxide concentration 30,000 ppm (54,000 mg/m3). When carbon dioxide is detected at the high level alarm, the system shall should activate an audible and visual alarm at a location approved by the jurisdiction having authority.

S12.6 SIGNAGE The inspection should verify that hazard identification signs are posted at the entrance to the building, room, enclosure, or enclosed area where the container is located. The warning sign shall should be at least 8 in (200mm) wide and 6 in. (150mm) high and indicate… S12.7 VALVES, PIPING, TUBING AND FITTINGS a) 1) Components shall should be rated for the operational temperatures and pressures encountered in the applicable circuit of the system. a) 2) All valves and fittings used on the LCDSV shall should be rated for the maximum allowable working pressure(MAWP) stamped on the tank. a) 3) All piping, hoses and tubing used in the LCDSV system shall should be rated for the working pressure of the applicable circuit in the system and have a burst pressure rating of at least four times the MAWP of the piping, hose or tubing.


Attachment Page 126

b) Relief Valves – The inspection should verify that each LCDSV shall should have at least one ASME/NB stamped & certified relief valve with a pressure setting at or below the MAWP of the tank. The relief valve shall should be suitable for the temperatures and flows experienced during relief valve operation. The minimum relief valve capacity shall should be designated by the manufacturer. Additional relief valves that do not require ASME stamps may be added per Compressed Gas Association pamphlet, CGA S-1.3 Pressure Relief Device Standards Part 3, Stationary Storage Containers for Compressed Gases, recommendations. Discharge lines from the relief valves shall should be sized in accordance with NBIC Part 2, Tables S12.7-a and S12.7-b. Note: Due to the design of the LCDSV the discharge line may be smaller in diameter than the relief valve outlet size. Caution: Company’s and or individuals filling or refilling LCDSV’s shall should be responsible for utilizing fill equipment that is acceptable to the manufacturer to prevent over pressurization of the vessel. c) Isolation Valves – The inspection should verify that each LCDSV shall should have an isolation valve installed on the fill line and tank discharge, or gas supply line in accordance with the following requirements:

1) Isolation valves shall should be located on the tank or at an accessible point as near to the storage tank a possible. 2) All valves shall should be designed or marked to indicate clearly whether they are open or closed. 3) All valves shall should be capable of being locked or tagged in the closed position for servicing. 4) Gas supply and liquid CO2 fill valves shall should be clearly marked for easy identification.

d) Safety Relief/Vent Lines – The inspection, where possible, should verify the integrity of the pressure relief/vent line from the pressure relief valve to outside vent line discharge fitting. All connections shall should be securely fastened to the LCDSV. The minimum size and length of the lines shall should be in accordance with NBIC Part 2, Tables S12.7-a and S12.7-b. Fittings or other connections may result in a localized reduction in diameter have been factored into the lengths given by the NBIC Part 2, Tables S12.7-a and S12.7-b. Table S12.7M-b Note: Due to the design of the LCDSV, the discharge line may be smaller in diameter than the relief valve outlet size but shall should not be smaller than that shown in tables NBIC Part 2, S12.7-a and -b.


Attachment Page 127

COMMENT: The above note is immediately after the metric Tables S12.7M-a and -b, but the referenced tables are the customary units S12.7-a and -b. This appears to be a mistake.


Attachment Page 128

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