nfpa 2 and nfpa 55 combined first draft meeting august 22 ... · m 08/09/2012 hyd-aaa david j....

NFPA 2 and NFPA 55 Combined First Draft Meeting

August 22-26 in Alexandria, VA Agenda and Schedule

Date and times: August 22-26 (Monday through Friday) 8:00 AM – 5:00 PM (Monday through Thursday) 8:00 AM – 12:00 noon (Friday)

Committee leaders:

Susan Bershad – NFPA Staff Liaison Carl Rivkin – Hydrogen Technology Committee chair (NFPA 2 – Hydrogen

Technologies Code) Rob Early – Industrial and Medical Gases Committee chair (NFPA 55 – Compressed

Gases and Cryogenic Fluids Code) Agenda: Review and act on public inputs for NFPA 2 material resident in NFPA 2 – Carl Rivkin, chair

Monday, August 22 – 8:00 AM to 5:00 PM Tuesday, August 23 – 8:00 AM to 12:00 noon NFPA 2 technical committee members review and act upon PIs. NFPA 55 committee

members are welcome to attend but are not required to do so. Review and act on public inputs for material extracted from NFPA 55 to NFPA 2 and for hydrogen storage requirements in NFPA 55 – Rob Early, chair

Tuesday, August 23 – 1:00 PM to 5:00 PM Wednesday, August 24 – 8:00 AM to 5:00 PM Thursday, August 25 – 8:00 AM to 12:00 noon NFPA 55 technical committee members review and act upon PIs. NFPA 2 technical

committee members attend and comment on PIs as part of the review process. Review and act on public inputs for NFPA 55 material not extracted to NFPA 2 – Rob Early, chair

Thursday, August 25 – 1:00 PM to 5:00 PM Friday, August 26 – 8:00 AM to 12:00 noon End of joint meeting NFPA 55 technical committee members review and act upon PIs. NFPA 2 technical

committee members are welcome to attend but are not required to do so.

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Address List No PhoneHydrogen Technology HYD-AAA

Susan Bershad07/25/2016

HYD-AAACarl H. RivkinChairNational Renewable Energy Laboratory15013 Denver West ParkwayGolden, CO 80401-3111Alternate: Robert M. Burgess

U 12/08/2015HYD-AAA

Nick BariloPrincipalPacific Northwest National LaboratoryPO Box 999Richland, WA 99352

U 7/28/2006

HYD-AAADenise BeachPrincipalFM Global1151 Boston-Providence TurnpikePO Box 9102Norwood, MA 02062-9102

I 08/17/2015HYD-AAA

Robert W. BoydPrincipalBoyd Hydrogen LLC6515 Wheeler StreetOakland, CA 94609

SE 10/23/2013

HYD-AAALarry M. DannerPrincipalGE Power & Water300 Garlington RoadGTTC Room 200DGreenville, SC 29615-0648

M 7/28/2006HYD-AAA

Larry M. DannerPrincipalGE Power & Water300 Garlington RoadGTTC Room 200DGreenville, SC 29615-0648

M 7/28/2006

HYD-AAAJoseph D. DiGiacomoPrincipalFlynn Burner Corporation12550 Lake Avenue, Suite 1703Lakewood, OH 44107

M 7/28/2006HYD-AAA

Rob EarlyPrincipalPraxair, Inc.PO Box 44Tonawanda, NY 14150-0044

M 08/09/2012

HYD-AAADavid J. FaresePrincipalAir Products and Chemicals, Inc.7201 Hamilton BoulevardAllentown, PA 18195

IM 7/28/2006HYD-AAA

Laurie B. FlorencePrincipalUL LLC333 Pfingsten RoadNorthbrook, IL 60062-2096

RT 8/9/2011

HYD-AAAFilippo GavelliPrincipalGexCon US4833 Rugby Avenue, Suite 100Bethesda, MD 20814-6111

SE 11/2/2006HYD-AAA

Stephen GoyettePrincipalNuvera Fuel Cells, Inc.129 Concord Road, Building 1Billerica, MA 01821Alternate: Bryan Gordon

M 7/28/2006

HYD-AAAMartin T. GreshoPrincipalFP2Fire, Inc.1140 Indian Peak RoadGolden, CO 80403-9403Alternate: Scott M. Heyworth

SE 7/28/2006HYD-AAA

Aaron HarrisPrincipalAir Liquide9807 Katy Freeway, Suite 100Houston, TX 77024

M 8/2/2010

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HYD-AAAThomas JosephPrincipalBethlehem Hydrogen Inc.5250 Deer Trail CircleEmmaus, PA 18049Alternate: Narendra Pal

M 7/28/2006HYD-AAA

Y. John KhalilPrincipalUnited Technologies Research Center (UTRC)411 Silver Lane, Mail Stop 129-30East Hartford, CT 06108

SE 3/4/2008

HYD-AAABrian LaddsPrincipalCalgary Fire DepartmentPO Box 2100, Station M, Mail Code 049Calgary, AB T2P 2M5 Canada

E 8/9/2011HYD-AAA

A. Christine LaFleurPrincipalSandia National LaboratoriesRisk & Reliability DepartmentPO Box 5800, MS-0909Albuquerque, NM 87185-0909

U 08/11/2014

HYD-AAACharles W. McKnightPrincipalBechtel National, Inc.2435 Stevens Center PlaceRichland, WA 99354-1874

SE 03/15/2007HYD-AAA

Lawrence C. Moulthrop, Jr.PrincipalProton Energy Systems Inc.10 Technology DriveWallingford, CT 06492

M 7/28/2006

HYD-AAAJoseph PlatiPrincipalCode Consultants, Inc.215 West 40th Street, 15th FloorNew York, NY 10018

SE 10/29/2012HYD-AAA

Marcia Jo PoxsonPrincipalMichigan Bureau of Fire ServicePO Box 30033Lansing, MI 48909-7926Alternate: R. Jeff Tanner

E 7/28/2006

HYD-AAAKaren I. QuackenbushPrincipalFuel Cell & Hydrogen Energy Association1211 Connecticut Avenue, NWWashington, DC 20036

M 7/28/2006HYD-AAA

Spencer QuongPrincipalToyota/Quong & Associates Inc.2355 Westwood Blvd., #502Los Angeles, CA 90064Alternate: Jacquelyn Birdsall

M 07/29/2013

HYD-AAAJerrold SamethPrincipalCompressed Gas Association, Inc.290 DeMott AvenueClifton, NJ 07011-3749Compressed Gas AssociationAlternate: Richard A. Craig

M 07/29/2013HYD-AAA

Alfred J. UnionePrincipalAECOM/URS Washington DivisionPO Box 618South Park, PA 15129

SE 7/26/2007

HYD-AAANathan WeyandtPrincipalSouthwest Research Institute6220 Culebra RoadSan Antonio, TX 78238-5166

RT 3/1/2011HYD-AAA

Robert P. WichertPrincipalRobert P. Wichert Professional Engineering Inc.6342 Parkcreek CircleCitrus Heights, CA 95621

SE 7/26/2007

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HYD-AAAJiann C. YangPrincipalNational Institute of Standards & TechnologyBuilding & Fire Research LaboratoryBuilding 224, Room B360100 Bureau Drive, MS 8662Gaithersburg, MD 20899Alternate: Kuldeep Prasad

RT 1/10/2008HYD-AAA

James C. MartinVoting AlternateShell Alternative Energies3301 Bollinger Crest CommonSan Ramon, CA 94583Voting Alt. to Shell Rep.

M 07/29/2013

HYD-AAAJacquelyn BirdsallAlternateToyota Engineering & Manufacturing North America, Inc.1630 West 186th StreetGardena, CA 90248-3807Principal: Spencer Quong

M 03/03/2014HYD-AAA

Robert M. BurgessAlternateNational Renewable Energy Laboratory15013 Denver West ParkwayGolden, CO 80401-3111Principal: Carl H. Rivkin

U 7/26/2007

HYD-AAARichard A. CraigAlternateCompressed Gas Association14501 George Carter Way, Suite 103Chantilly, VA 20151Principal: Jerrold Sameth

M 8/9/2011HYD-AAA

Bryan GordonAlternateNuvera Fuel Cells, Inc.129 Concord Road, Building 1Billerica, MA 01821Principal: Stephen Goyette

M 07/29/2013

HYD-AAAScott M. HeyworthAlternateFP2Fire, Inc.10810 SW 142 Ave.Miami, FL 33186Principal: Martin T. Gresho

SE 8/5/2009HYD-AAA

Narendra PalAlternateBethlehem Hydrogen Inc.100 Ramapo Trail, Apt. H13Allentown, PA 18104-8595Principal: Thomas Joseph

M 08/11/2014

HYD-AAAKuldeep PrasadAlternateNational Institute of Standards & TechnologyBuilding & Fire Research Laboratory100 Bureau Drive, MS 8663Gaithersburg, MD 22182Principal: Jiann C. Yang

RT 8/2/2010HYD-AAA

R. Jeff TannerAlternateMichigan Department of Environmental QualityPO Box 30426Lansing, MI 48909-7926Principal: Marcia Jo Poxson

E 10/29/2012

HYD-AAASusan BershadStaff LiaisonNational Fire Protection Association1 Batterymarch ParkQuincy, MA 02169-7471

7/11/2012

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Address List No PhoneIndustrial and Medical Gases IMG-AAA


IMG-AAARob EarlyChairPraxair, Inc.PO Box 44Tonawanda, NY 14150-0044Alternate: Rick Ginn

M 11/2/2006IMG-AAA

John J. AnicelloPrincipalAirgas Inc.29604 11th Place SouthFederal Way, WA 98003-3727Alternate: Michael G. Pirrello

M 10/10/1997

IMG-AAAWilliam H. BarlenPrincipalBarlen and Associates, Inc.24 Gettysburg CourtAllentown, NJ 08501

SE 7/17/1998IMG-AAA

Rodney L. BarnesPrincipalUS Department of EnergyPO Box 2009Oak Ridge, TN 37831-8009

U 3/21/2006

IMG-AAADenise BeachPrincipalFM Global1151 Boston-Providence TurnpikePO Box 9102Norwood, MA 02062-9102

I 08/17/2015IMG-AAA

Erik W. ChristiansenPrincipalExponent, Inc.5401 McConnell AvenueLos Angeles, CA 90066-7027Alternate: Robert W. Whittlesey

SE 8/2/2010

IMG-AAAMichael CiottiPrincipalLinde North America, Inc.575 Mountain Avenue F-WingNew Providence, NJ 07974-2097

M 12/08/2015IMG-AAA

Julie V. CorderoPrincipalSandia National LaboratoriesPO Box 5800, MS 0909Albuquerque, NM 87185

U 7/23/2008

IMG-AAADavid J. De FinaPrincipalSterigenics International, Inc.2015 Spring Road, Suite 650Oak Brook, IL 60523 Alternate: Brian D. Musch

IM 7/29/2005IMG-AAA

Kenneth FegleyPrincipalAir Products and Chemicals, Inc.7201 Hamilton BoulevardAllentown, PA 18195-1501Compressed Gas AssociationEquipmentAlternate: David J. Farese

IM 03/05/2012

IMG-AAAAlejandro GonzalezPrincipalKryogenifex121 NW 24th StreetMiami, FL 33127

M 8/9/2011IMG-AAA

Martin T. GreshoPrincipalFP2Fire, Inc.1140 Indian Peak RoadGolden, CO 80403-9403Alternate: Scott M. Heyworth

SE 4/14/2005

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IMG-AAAGerald T. HayesPrincipalAir Liquide America1230 West Washington, Suite 212Tempe, AZ 85281Compressed Gas AssociationNonliquefied Gases Alternate: Richard A. Craig

IM 1/10/2008IMG-AAA

Anthony J. Lachawiec, Jr.PrincipalIntel Corporation2501 NW 229th AvenueHillsboro, OR 97124Alternate: Scott E. Swanson

M 07/29/2013

IMG-AAAFrank A. LicariPrincipalUS Department of Transportation5833 New England Woods DriveBurke, VA 22015

E 10/18/2011IMG-AAA

Eugene Y. NgaiPrincipalChemically Speaking LLC26 Casper Berger RoadWhitehouse Station, NJ 08889

SE 1/16/2003

IMG-AAARobert R. NiiPrincipalCH2M-WG Idaho, LLC1580 Sawtell StreetIdaho Falls, ID 83402-1808

U 10/23/2003IMG-AAA

Richard P. PalluziPrincipalRichard Palluzi LLC72 Summit DriveBasking Ridge, NJ 07920-1962

SE 10/27/2009

IMG-AAADiana C. ParksPrincipalState of Alaska Department of Public SafetyDivision of Fire & Life Safety5700 East Tudor RoadAnchorage, AK 99507

E 3/1/2011IMG-AAA

Carl H. RivkinPrincipalNational Renewable Energy Laboratory15013 Denver West ParkwayGolden, CO 80401-3111

U 03/03/2014

IMG-AAADavid A. RohrigPrincipalPacific Northwest National Laboratory902 Battelle BoulevardPO Box 999, MSIN J2-38Richland, WA 99352

U 10/23/2013IMG-AAA

Jerrold SamethPrincipalCompressed Gas Association, Inc.290 DeMott AvenueClifton, NJ 07011-3749Compressed Gas AssociationCryogenic GasesAlternate: Stuart J. Muller

IM 07/29/2013

IMG-AAAWilliam J. Satterfield, IIIPrincipalHydrogen Safety, LLC/Rode & Associates, LLC35 Brookwood RoadBristol, RI 02809-1206

SE 1/16/1998IMG-AAA

Michael W. St. ClairPrincipal8830 Long RoadOstrander, OH 43061NFPA Industrial Fire Protection Section

U 1/1/1994

IMG-AAARandolph ViscomiPrincipalARC Specialty Products CorporationDivision of Balchem, Inc.20 Cliff CourtSuccasunna, NJ 07876

IM 4/1/1995IMG-AAA

Jonathan C. WillardPrincipalAcute Medical Gas Services100 Zachary Road 3Manchester, NH 03109

SE 8/2/2010

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IMG-AAAEdgar Wolff-KlammerPrincipalUL LLC333 Pfingsten RoadNorthbrook, IL 60062-2096Alternate: Joseph M. Bablo

RT 03/07/2013IMG-AAA

Joseph M. BabloAlternateUL LLC333 Pfingsten RoadNorthbrook, IL 60062-2096Principal: Edgar Wolff-Klammer

RT 03/07/2013

IMG-AAARichard A. CraigAlternateCompressed Gas Association14501 George Carter Way, Suite 103Chantilly, VA 20151Nonliquefied GasesPrincipal: Gerald T. Hayes

IM 8/9/2011IMG-AAA

David J. FareseAlternateAir Products and Chemicals, Inc.7201 Hamilton BoulevardAllentown, PA 18195Compressed Gas AssociationEquipmentPrincipal: Kenneth Fegley

IM 08/11/2014

IMG-AAARick GinnAlternatePraxair, Inc.8376 Reading RoadReading, OH 45237Principal: Rob Early

M 7/1/1996IMG-AAA

Scott M. HeyworthAlternateFP2Fire, Inc.10810 SW 142 Ave.Miami, FL 33186Principal: Martin T. Gresho

SE 8/5/2009

IMG-AAAStuart J. MullerAlternateMatheson61 Grove StreetGloucester, MA 01930Compressed Gas AssociationCryogenic GasesPrincipal: Jerrold Sameth

IM 03/03/2014IMG-AAA

Brian D. MuschAlternateSterigenics US, LLC2015 Spring Road, Suite 650Oak Brook, IL 60523Principal: David J. De Fina

IM 7/26/2007

IMG-AAAMichael G. PirrelloAlternateAirgas529 Farview AvenueHatfield, PA 19440-3015Principal: John J. Anicello

M 07/29/2013IMG-AAA

Scott E. SwansonAlternateIntel Corporation2501 NW 229th AvenueHillsboro, OR 97124Principal: Anthony J. Lachawiec, Jr.

M 10/27/2009

IMG-AAARobert W. WhittleseyAlternateExponent, Inc.5401 Mcconnell AveLos Angeles, CA 90066-7027Principal: Erik W. Christiansen

SE 08/11/2014IMG-AAA

Charles B. HenriciMember Emeritus1812 Fox Run Drive, Unit CElk Grove Village, IL 60007-7013

SE 1/1/1966

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IMG-AAASusan BershadStaff Liaison National Fire Protection Association1 Batterymarch ParkQuincy, MA 02169-7471

7/11/2012

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Minutes of Meeting – NFPA 55 Second Draft Meeting

NREL, Golden, CO July 14th – 15th, 2014

Member Attending

Rob Early – chair Yes Member

John Anicello Yes Member

William Barlen Yes Member

Rodney Barnes No Member

Erik Christiansen Yes Member

Therese Cirone No Member

Julie Cordero Yes Member

David De Fina No Member

Alejandro Gonzalez No Member

Martin Gresho Yes Member

Gerry Hayes Yes Member

Anthony Lachawiec Yes Member

Frank Licari No Member

Glenn Mahnken No Member

Eugene Ngai Yes Member

Robert Nii No Member

Richard Palluzi Yes Member

Diana Parks Yes Member

Jerry Sameth Yes Member

Carl Rivkin Yes Member

David Rohrig Yes Member

William Satterfield No Member

Mike St. Clair No Member

Randolph Viscomi Yes Member

Jonathan Willard Yes Member

Edgar Wolff-Klammer No Member

Joseph Balbo No Alternate

Richard Craig Yes Alternate

Kenneth Fegley No Voting Alternate

Rick Ginn Yes Alternate

Scott Heyworth No Alternate

Stuart Muller No Alternate

Brian Musch No Alternate

Michael Pirrello No Alternate

Scott Swanson No Alternate

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Chuck Henrici Yes Member Emeritus

Bob Boyd Yes Guest – NFPA 2

Aaron Harris Yes Guest

Nick Barilo yes Guest – NFPA 2

Marcia Poxson Yes Guest – NFPA 2

Karen Hall Yes Guest – NFPA 2

Steve Goyette Yes Guest – NFPA 2

Joseph Plati Yes Guest – NFPA 2

Brian Ladds Yes Guest – NFPA 2

Laurie Florence Yes Guest – NFPA 2

Susan Bershad Yes. NFPA

1. The meeting was called to order by the NFPA 55 chair, Rob Early, at 9:00 AM on July 14th. 2. Susan Bershad from NFPA gave an overview of the new process and an update as to the

document schedule and committee membership. 3. The committee reviewed and acted on the non-hydrogen related public comments received

for NFPA 55 on July 14th 4. The committee reviewed a letter received from the New England Fire Marshalls regarding the

regulation of CNG tube trailers being used as fuel for facilities that are not serviced by natural gas pipelines. The committee is setting up a task group, chaired by Rob Early, to work with the group on reviewing the applicable requirements in 55 and determining if additional requirements should be proposed. The task group roster is as follows:

Rob Early – chair Rick Ginn Jonathan Willard Rich Craig John Anicello Aaron Harris

5. Representatives from Oberon fuels gave a presentation on dimethyl ether as an alternative vehicular fuel. Oberon would like to work with the NFPA 55 Technical Committee to develop new material for the next revision cycle on requirements for dimethyl ether. Marty Gresho will be chairing a task group that will be looking at this issue. The task group roster is as follows:

Marty Gresho – chair Erik Christiansen Bill Barlen Bob Boyd

6. In addition to the formation of the two task groups listed above, the committee added Nick Barilo and Eugene Ngai to the LH2 separation distances task group to work on the issue of flammable gas separation distances in Chapter 7.

7. The committee continued on July 15th at 8 am with the review of hydrogen related public comment for NFPA 55 and public comment for NFPA 2 on material that is extracted from 55. This material was reviewed by both technical committees.

8. The NFPA 55 meeting was adjourned at 3 pm on Tuesday, July 15th at 3 pm. 9. The next meeting of the IMG Technical Committee will be a first draft meeting for NFPA 51,

which is an annual 2017 document. This will be held in the fall of 2015.

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Minutes of Meeting – NFPA 2 Second Draft Meeting

NREL, Golden, CO July 16th – 17th, 2014

Member Attending Member

Marty Gresho Yes Yes

Nick Barilo Yes Yes

Robert Boyd Yes Yes

Robert Burgess Yes Yes

Larry Danner Yes Yes

Joseph DiGiacomo Yes Yes

Rob Early Yes Yes

Dave Farese Yes Yes

Laurie Florence Yes Yes

Filippo Gavelli No Yes

Steve Goyette Yes Yes

Karen Hall Yes Yes

Doug Horne No Yes

Thomas Joseph No Yes

Mardy Kazarians No Yes

Y. Khalil No Yes

Quon Kwan No Yes

Brian Ladds Yes Yes

Glenn Mahnken No Yes

Charles McKnight No Yes

Gregory Milewski No Yes

Larry Moulthrop Yes Yes

Marcia Poxson Yes Yes

Spencer Quong Yes Yes

Jerry Sameth Yes Yes

Al Unione No Yes

Nathan Weyandt No Yes

Robert Wichert No Yes

Jiann Yang No Yes

Joseph Plati Yes Voting Alternate

Jacquelyn Birdsall No Alternate

Rich Craig Yes Alternate

John Dimmick No Alternate

Bryan Gordon No Alternate


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James Martin No Alternate

Kuldeep Prasad No Alternate

R. Tanner No Alternate

Diana Parks Yes Guest – NFPA 55

Chris LaFleur Yes Guest

Aaron Harris Yes Guest

Rick Ginn Yes Guest – NFPA 55

Rich Palluzi Yes Guest – NFPA 55

Julie Cordero Yes Guest – NFPA 55

Anthony Lachawiez Yes Guest - NFPA 55

Carl Rivkin Yes Guest – NFPA 55

Susan Bershad – NFPA Yes No

Eric Nette - NFPA Yes- by web

1. The meeting was called to order by the NFPA 2 chair, Marty Gresho, at 8:00 AM on July 16th. 2. Susan Bershad from NFPA gave an overview of the new process and an update as to the

document schedule and committee membership. 3. The committee reviewed and acted on the public comments received for NFPA 2. Note that

the public comment received on material extracted from NFPA 55 was reviewed and acted on by the 55 technical committee the previous day, with input and recommendations from the NFPA 2 technical committee.

4. The committee reviewed the current task groups. Two groups will continue into the upcoming revision cycle, the LH2 separations task group (which is joint with the NFPA 55 committee), and the enclosure task group. See the attached task group for the rosters for these two groups.

5. The enclosure task group will continue work with the goal of creating a TIA concurrent with the processing of the document. The goal would be to process the TIA this fall. The group was close to completing its final document, but has not reached consensus.

6. The concept of chapter leads was reviewed. An updated list of chapter leads is attached. The chapter lead is to act as a resource for questions from users on the Chapter.

7. The next meeting of the technical committee will be a first draft meeting for the next revision cycle, which will be A2018. This will take place in August or September of 2016.

8. The meeting was adjourned at 5:00 pm on Thursday, July 18th.

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Task Group Name Purpose, Scope and Roster Status

Liquid Hydrogen Separation Distances – Joint 2/55 (Active)

This Task Group will continue its efforts on LH2 separation distances. Review of flammable gas separation distances in 7.6.2 was added to the scope at the second draft meeting. Carl Rivkin is the Chair. Scope: : Validate or revise the existing prescriptive hydrogen separation distances in NFPA 55 using new research and continue use of risk informed processes. Validate or revise the basis for flammable gas separation distances in 7.6.2 of NFPA 55. Roster: Carl Rivkin (chair), Chuck Henrici, Chris LaFleur, Dave Farese, Ken Fegley, Marcia Poxson, Marty Gresho, Rob Early, Rich Craig, Bob Boyd, Spencer Quong, Tom Joseph, Aaron Harris, Nick Barilo, Eugene Ngain

The goal of this committee is to generate material for public input for the next revision cycle.

Enclosures (Active - New Task Group)

Scope: Develop a technical basis for creating prescriptive (or possibly performance based) code requirements for the range of enclosures used for hydrogen systems from the smallest to the largest. Resulting Actions: Develop prescriptive and / or performance based code requirements regarding the use of cabinets and enclosures for storage, compression or dispense systems or any combination thereof. Roster: . Larry Moulthrop (Chair), Dave Farese., Nick Barilo, Tom Joseph, Aaron Harris, Steve Goyette, Bob Boyd, Jennifer Hamilton, Spencer Quong, Laurie F. Carl Rivkin

This group will continue work with focus on creating material for a TIA to be processed concurrent with the ballot schedule.

Updated Chapter Leads

Chapter Title Primary Contact

1 Administration Martin Gresho

2 Referenced Publications Joe Plati

3 Definitions Karen Hall

4 General Fire Safety Requirements Nick Barilo

5 Performance Based Option Chris LaFleur

6 General Hydrogen Requirements Nick Barilo

7 Gaseous Hydrogen Nick Barilo

8 Liquefied Hydrogen Rob Early

9 Explosion Protection Martin Gresho

10 GH2 Vehicle Fueling Facilities Aaron Harris

11 LH2 Hydrogen Fueling Facilities Bob Boyd

12 Hydrogen Fuel Cell Power Systems Steve Goyette

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Chapter Title Primary Contact

13 Hydrogen Generation Systems Larry Moulthrop

14 Combustion Applications Larry Danner

15 Special Atmosphere Applications Larry Danner

16 Laboratory Operations Nick Barilo

17 Parking Garages Marcia Poxson

18 Repair Garages Marcia Poxson

Annex A Explanatory Material See Chapter Representatives

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Minutes of Meeting – NFPA 2 Continuation of Second Draft Meeting

Web Meeting/Teleconference October 23, 2014

11 AM – 12:30 PM ET

Member Attending Member

Marty Gresho -Chair Yes Yes

Nick Barilo Yes Yes

Robert Boyd Yes Yes

Robert Burgess No Yes

Larry Danner Yes Yes

Joseph DiGiacomo No Yes

Rob Early Yes Yes

Dave Farese Yes Yes

Laurie Florence Yes Yes

Filippo Gavelli Yes Yes

Steve Goyette Yes Yes

Karen Hall Yes Yes

Doug Horne No Yes

Thomas Joseph Yes Yes

Mardy Kazarians No Yes

Y. Khalil No Yes

Quon Kwan No Yes

Brian Ladd Yes Yes

Gregory Milewski No Yes

Larry Moulthrop Yes Yes

Marcia Poxson Yes Yes

Spencer Quong Yes Yes

Jerry Sameth Yes Yes

Al Unione No Yes

Nathan Weyandt No Yes

Robert Wichert No Yes

Jiann Yang No Yes

Joseph Plati Yes Voting Alternate

Jacquelyn Birdsall No Alternate

Rich Craig No Alternate

John Dimmick No Alternate

Bryan Gordon No Alternate

Scott Heyworth Yes Alternate

James Martin No Alternate

Kuldeep Prasad No Alternate

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R. Tanner No Alternate

Chris LaFleur Yes Alternate

Susan Bershad – NFPA Yes No

1. The meeting was called to order by the NFPA 2 Chair, Marty Gresho, at 11:00 AM ET on

October 23rd. 2. Susan Bershad from NFPA gave an overview of the ballot schedule and the process for

reconsideration of the committee’s action on SR-57, the material of hydrogen equipment enclosures that was passed at the second draft meeting in July.

3. Nick Barilo reviewed the Chapter 7 draft of the material extracted from Chapter 7 and 10 of NFPA 55. This material was approved by the technical committee and will be incorporated into the second draft ballot.

4. The committee voted to reconsider its action on SR-57 and the associated definition for hydrogen equipment enclosures in Chapter 3. The work of the enclosure task group was presented and discussed. This material was approved by the committee and will be incorporated into the second draft ballot as a proposed second revision.

5. The meeting was adjourned at 12:30 PM.

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Minutes of Meeting – NFPA 51 First Draft Meeting

Web Meeting November 17th, 2015, 1 PM ET

Member Attending

Rob Early – chair Yes Member

John Anicello Yes Member

William Barlen No Member

Rodney Barnes No Member

Denise Beach Yes Member

Erik Christiansen No Member

Julie Cordero No Member

Ken Fegley Yes Member

David De Fina No Member

Alejandro Gonzalez No Member

Martin Gresho No Member

Gerry Hayes No Member

Anthony Lachawiec No Member

Frank Licari No Member

Eugene Ngai No Member

Robert Nii No Member

Diana Parks Yes Member

Carl Rivkin Yes Member

David Rohrig No Member

Jerry Sameth Yes Member

William Satterfield No Member

Mike St. Clair Yes Member

Randolph Viscomi No Member

Jonathan Willard No Member

Edgar Wolff‐Klammer Yes Member

Joseph Balbo No Alternate

Richard Craig Yes Alternate

Dave Farese No Alternate

Rick Ginn Yes Alternate


Steward Muller Yes Alternate

Brian Musch No Alternate

Michael Pirrello No Alternate

Scott Swanson No Alternate

Robert Whittlesley No Alternate

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Chuck Henrici Yes Member Emeritus

Susan Bershad NFPA

1. The meeting was called to order by the chair, Rob Early, at 1:00 PM on November 17th

2. Susan Bershad, NFPA staff, gave an update on committee membership, the A2017 document

schedule, and the procedures for first draft meetings.

3. Rob Early gave a summary of the status of NFPA 55. The 2016 edition of 55 has been issued and printed. The TIA developed by the CNG task group has been balloted and will be considered at the December 2015 Standards Council meeting. Another TIA on fire barrier walls is being processed and will be considered at the April Standards Council meeting.

4. Rob also provided an update on the Hydrogen Separation Distance Task Group, which is a joint

task group between the NFPA 2 and the NFPA 55 committees. This group is working on revisions to the separation distance tables for gaseous and liquid hydrogen.

5. The committee reviewed and acted on public input for NFPA 51, and created first revisions to

the document. The committee voted to extract the material from Chapter 15 of NFPA 55 on MATS Fire Protection into NFPA 51. It was noted that there were several changes made to this material in comparison to the original TIA from 2012.

6. The next meeting of the committee will be the first draft meeting for NFPA 55, which is an

A2018 document. The Public Input closing date for NFPA 55 is June 29th, 2016. This meeting is tentatively scheduled for the week of September 12th, 2016 in the vicinity of Dulles airport in Virginia.

7. The committee discussed the new NFPA extract policy and the effect it may have on NFPA 2.

NFPA 2 extracts heavily from NFPA 55. The new policy does not allow for extracts from documents in the same revision cycle. Currently NFPA 55 and NFPA 2 are both in the A2018 revision cycle. Susan is working with Standards Administration to clarify this issue so that the committees can continue to work jointly on revisions to the documents, and so that the changes can occur concurrently.

8. The meeting was adjourned at 2:30 PM ET.

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Tentative Interim Amendment

NFPA 2 Hydrogen Technologies Code

2016 Edition Reference: 18.3.3 TIA 16-1 (SC 15-8-13 / TIA Log #1178) Note: Text of the TIA was issued and incorporated into the document prior to printing of the standard, therefore no separate publication is necessary. 1. Revise 18.3.3 to read as follows: 18.3.3 Gas Detection System. Major repair garages shall be provided with an approved hydrogen gas

detection system such that gas can be detected where vehicle hydrogen fuel storage systems are serviced or indoor defueling occurs.

Issue Date: August 18, 2015 Effective Date: September 7, 2015

(Note: For further information on NFPA Codes and Standards, please see www.nfpa.org/codelist) Copyright © 2015 All Rights Reserved

NATIONAL FIRE PROTECTION ASSOCIATION

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NFPA® 55

Compressed Gases and Cryogenic Fluids Code

2016 Edition

Reference: 1.1.1 TIA 16-1 (SC 15-12-3 / TIA Log #1195) Pursuant to Section 5 of the NFPA Regulations Governing the Development of NFPA Standards, the National Fire Protection Association has issued the following Tentative Interim Amendment to NFPA 55, Compressed Gases and Cryogenic Fluids Code, 2016 edition. The TIA was processed by the Technical Committee on Industrial and Medical Gases and was issued by the Standards Council on December 8, 2015, with an effective date of December 28, 2015. A Tentative Interim Amendment is tentative because it has not been processed through the entire standards-making procedures. It is interim because it is effective only between editions of the standard. A TIA automatically becomes a public input of the proponent for the next edition of the standard; as such, it then is subject to all of the procedures of the standards-making process. 1. Add new Appendix material for 1.1.1 to read as follows:

1.1.1* Applicability. This code shall apply to the installation, storage, use, and handling of compressed gases and cryogenic fluids in portable and stationary cylinders, containers, equipment, and tanks in all occupancies. A.1.1.1 The term “portable” points out the application of this code to systems other than those considered to be permanent; i.e., systems where the equipment is installed on foundations and meant to stay in place for a considerable period of time. This code applies to portable and temporary systems, including the two types listed below: (1) Equipment that is ordinarily used for the transportation and delivery of compressed gases or cryogenic fluids but that is

located at a customer (end user) location and used for storage of compressed gases or cryogenic fluids. One example is a compressed gas tube trailer that is dropped at a customer location and left in place to supply the compressed gas to the customer use point. Another example is a cryogenic liquid trailer that is left at a customer location to supply cryogenic liquids to the customer use point (or vaporized into gas before going to the use point).

(2) Equipment used for the temporary supply of compressed gases or cryogenic fluids at a customer location. An example is a portable cryogenic tank that is mounted on a trailer and dropped at the customer location and not always connected to foundations by anchor bolts. Such a supply system may be in place for a matter of weeks as opposed to a more permanent system that is left in place for years.

Some of the requirements of this code are not applicable to this type of equipment. For example, some sections of this code mandate that the equipment be anchored to permanent foundations. Equipment with wheels for transportation do not need to be anchored. However, auxiliary equipment, such as pressure reducing stations, would need to be anchored to a foundation. The user must determine which sections of the code apply to equipment and which sections do not apply. It is not the intent of this code to regulate transportation and delivery equipment when that equipment is used only to deliver product to a storage system at a customer location. For example, a cryogenic liquid trailer that delivers product into a storage system (and does not stay on site after delivering product) does not have to meet the requirements of this code. The trailer is

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governed by DOT/TC requirements. Another example is a compressed gas tube trailer that delivers product to a permanent storage system and does not stay on site to supply product to the end user. Portable equipment is sometimes transported with product loaded in the storage vessel or may be shipped with the vessel empty, to be filled at the customer location. Equipment that is designed to be transported with product in it is governed by DOT/TC regulations. Nothing in this code is intended to overrule the DOT/TC regulations governing the use of such equipment.

Issue Date: December 8, 2015 Effective Date: December 28, 2015

(Note: For further information on NFPA Codes and Standards, please see www.nfpa.org/codelist) Copyright © 2015 All Rights Reserve


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NFPA® 55

Compressed Gases and Cryogenic Fluids Code

2016 Edition

Reference: 11.3.2.2.1 and 11.3.2.2.2* TIA 16-2 (SC 16-4-7 / TIA Log #1208) Pursuant to Section 5 of the NFPA Regulations Governing the Development of NFPA Standards, the National Fire Protection Association has issued the following Tentative Interim Amendment to NFPA 55, Compressed Gases and Cryogenic Fluids Code, 2016 edition. The TIA was processed by the Technical Committee on Industrial and Medical Gases, and was issued by the Standards Council on April 6, 2016, with an effective date of April 26, 2016. A Tentative Interim Amendment is tentative because it has not been processed through the entire standards-making procedures. It is interim because it is effective only between editions of the standard. A TIA automatically becomes a public input of the proponent for the next edition of the standard; as such, it then is subject to all of the procedures of the standards-making process. 1. Revise 11.3.2.2.1 and 11.3.2.2.2* to read as follows:

11.3.2.2.1 The distances in 1, 7, 8, 10, 11, and 12 in Table 11.3.2.2 shall be permitted to be reduced by two-thirds, but to not less than 5 ft (1.5 m), for insulated portions of the system. 11.3.2.2.2* The distances in 1, 7, 8, 10, 11, and 12 in Table 11.3.2.2 shall be permitted to be reduced by the use of fire barrier walls having a fire resistance rating of not less than 2 hours when constructed in accordance with 8.7.2.1 and 11.3.2.2.

Issue Date: April 6, 2016 Effective Date: April 26, 2016

(Note: For further information on NFPA Codes and Standards, please see www.nfpa.org/codelist) Copyright © 2016 All Rights Reserve


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Public Input No. 55-NFPA 2-2016 [ Global Input ]

Type your content here ...

Change "Material Safety Data Sheet(s)/MSDS" to "Safety Data Sheet(s)/SDS" throughout this document.

Statement of Problem and Substantiation for Public Input

OSHA terminology has changed from "Material Safety Data Sheets" to "Safety Data Sheets".

Submitter Information Verification

Submitter Full Name: Karen Quackenbush

Organization: Fuel Cell & Hydrogen Energy Assoc.

Affilliation: FCHEA

Street Address:

City:

State:

Zip:

Submittal Date: Fri May 27 12:45:32 EDT 2016

National Fire Protection Association Report http://submittals.nfpa.org/TerraViewWeb/ContentFetcher?commentPara...

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Public Input No. 4-NFPA 2-2016 [ Chapter 2 ]

Chapter 2 Referenced Publications

2.1 General.

The documents or portions thereof listed in this chapter are referenced within this code and shall be considered part of the requirements of this document.

2.2 NFPA Publications.

National Fire Protection Association, 1 Batterymarch Park, Quincy, MA 02169-7471.

NFPA 1, Fire Code , 2015 edition.

NFPA 10, Standard for Portable Fire Extinguishers, 2013 edition.

NFPA 11, Standard for Low-, Medium-, and High-Expansion Foam, 2015 edition.

NFPA 12, Standard on Carbon Dioxide Extinguishing Systems, 2015 edition.

NFPA 12A, Standard on Halon 1301 Fire Extinguishing Systems, 2015 edition.

NFPA 13, Standard for the Installation of Sprinkler Systems, 2016 edition.

NFPA 14, Standard for the Installation of Standpipe and Hose Systems, 2013 edition.

NFPA 15, Standard for Water Spray Fixed Systems for Fire Protection, 2012 edition.

NFPA 17, Standard for Dry Chemical Extinguishing Systems, 2013 edition.

NFPA 17A, Standard for Wet Chemical Extinguishing Systems, 2013 edition.

NFPA 24, Standard for the Installation of Private Fire Service Mains and Their Appurtenances, 2016 edition.

NFPA 25, Standard for the Inspection, Testing, and Maintenance of Water-Based Fire Protection Systems, 2014 edition.

NFPA 30, Flammable and Combustible Liquids Code, 2015 edition.

NFPA 30A, Code for Motor Fuel Dispensing Facilities and Repair Garages, 2015 edition.

NFPA 31, Standard for the Installation of Oil-Burning Equipment, 2015 edition.

NFPA 37, Standard for the Installation and Use of Stationary Combustion Engines and Gas Turbines, 2014 edition.

NFPA 45, Standard on Fire Protection for Laboratories Using Chemicals, 2015 edition.

NFPA 51, Standard for the Design and Installation of Oxygen–Fuel Gas Systems for Welding, Cutting, and Allied Processes, 2013 edition.

NFPA 51B, Standard for Fire Prevention During Welding, Cutting, and Other Hot Work, 2014 edition.

NFPA 52, Vehicular Gaseous Fuel Systems Code, 2013 edition.

NFPA 54, National Fuel Gas Code, 2015 edition.

NFPA 55, Compressed Gases and Cryogenic Fluids Code, 2016 edition.

NFPA 58, Liquefied Petroleum Gas Code, 2014 edition.

NFPA 68, Standard on Explosion Protection by Deflagration Venting, 2013 edition.

NFPA 69, Standard on Explosion Prevention Systems, 2014 edition.

NFPA 70® , National Electrical Code®, 2014 edition.

NFPA 72® , National Fire Alarm and Signaling Code, 2016 edition.

NFPA 79, Electrical Standard for Industrial Machinery, 2015 edition.

NFPA 80, Standard for Fire Doors and Other Opening Protectives, 2016 edition.

NFPA 82, Standard on Incinerators and Waste and Linen Handling Systems and Equipment, 2014 edition.

NFPA 86, Standard for Ovens and Furnaces, 2015 edition.

NFPA 90A, Standard for the Installation of Air-Conditioning and Ventilating Systems, 2015 edition.

NFPA 91, Standard for Exhaust Systems for Air Conveying of Vapors, Gases, Mists, and Particulate Solids, 2015 edition.

NFPA 101® , Life Safety Code®, 2015 edition.

NFPA 110, Standard for Emergency and Standby Power Systems, 2016 edition.

NFPA 211, Standard for Chimneys, Fireplaces, Vents, and Solid Fuel–Burning Appliances, 2013 edition.

NFPA 259, Standard Test Method for Potential Heat of Building Materials, 2013 edition.

NFPA 496, Standard for Purged and Pressurized Enclosures for Electrical Equipment, 2013 edition.

NFPA 497, Recommended Practice for the Classification of Flammable Liquids, Gases, or Vapors and of Hazardous (Classified) Locations for ElectricalInstallations in Chemical Process Areas, 2012 edition.

NFPA 704, Standard System for the Identification of the Hazards of Materials for Emergency Response, 2012 edition.

NFPA 750, Standard on Water Mist Fire Protection Systems, 2014 edition.

NFPA 853, Standard for the Installation of Stationary Fuel Cell Power Systems, 2015 edition.

NFPA 2001, Standard on Clean Agent Fire Extinguishing Systems, 2015 edition.

2.3 Other Publications.


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2.3.1 ANSI Publications.

American National Standards Institute, Inc., 25 West 43rd Street, 4th Floor, New York, NY 10036.

ANSI A13.1, Scheme for Identification of Piping Systems , 2007.

ANSI C2, National Electrical Safety Code , 2012.

ANSI /CSA/AM FC 1, American National Standard for Fuel Fuel cell technologies: Part 3-100: Stationary Fuel Cell Power Systems - Safety , 20122014 .

ANSI/CSA/AM FC 3, American National Standard/CSA American Standard for Portable Fuel Cell Power Systems, 2004.

ANSI Z535.2, Environmental and Facility Safety Signs, 2011.

ANSI Z535.3, Criteria for Safety Symbols, 2011.

ANSI Z535.4, Product Safety Signs and Labels, 2011.

2.3.2 ASME Publications.

American Society of Mechanical Engineers ASME International , Two Park Avenue, New York, NY 10016-5990.

ASME A13.1, Scheme for the Identification of Piping Systems, 2007 2015 .

ASME B31.3, Process Piping, 2012 2016 .

ASME B31.12, Hydrogen Piping and Pipelines, 2011 2014 .

ASME Boiler and Pressure Vessel Code, Section VIII, 2013 2015 .

ASME International, Boiler and Pressure Vessel Code, “Rules for the Construction of Unfired Pressure Vessels,” Section VIII, 2013 2015 .

2.3.3 ASTM Publications.

American Society for Testing and Materials ASTM International , 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959.

ASTM E84, Standard Test Method for Surface Burning Characteristics of Building Materials, 2014 2015b .

ASTM E136, Standard Test Method for Behavior of Materials in a Vertical Tube Furnace at 750°C, 2012 2016 .

ASTM E1529, Determining Effects of Large Hydrocarbon Pool Fire on Structural Members and Assemblies, 2013 2014a .

ASTM E1591, Standard Guide for Data for Fire Models, 2013.

ASTM E2652, Standard Test Method for Behavior of Materials in a Tube Furnace with a Cone-shaped Airflow Stabilizer, at 750°C, 2012 2016 .

2.3.4 CGA Publications.

Compressed Gas Association, 14501 George Carter Way, Suite 103, Chantilly, VA 20151-2923.

CGA C-7, Guide to the Preparation of Precautionary Labeling and Marking Classification and Labeling of Compressed Gas Containers Gasses ,2011 2014 .

CGA G-5.5, Hydrogen Vent Systems, 2014.

CGA P-1, Safe Handling of Compressed Gases in Containers, 2008 2015 .

CGA S-1.1, Pressure Relief Device Standards — Part 1 — Cylinders for Compressed Gases, 2011.

CGA S-1.2, Pressure Relief Device Standards — Part 2 — Cargo and Portable Tanks for Compressed Gases, 2009.

CGA S-1.3, Pressure Relief Device Standards — Part 3 — Stationary Storage Containers for Compressed Gases, 2008.

2.3.5 * CTC Publications.

Canadian Transport Commission, Queen's Printer, Ottawa, Ontario, Canada. (Available from the Canadian Communications Group Publication Centre,Ordering Department, Ottawa, Canada K1A 0S9.)

Transportation of Dangerous Goods Regulations.

2.3.6 ICC Publications.

International Code Council, 500 New Jersey Avenue, NW, 6th Floor, Washington, DC 20001.

, International Fire Code (IFC), 2015.

International Fuel Gas Code (IFGC), 2015.

2.3.7 IEEE Publications.

IEEE, 449 & 501 Hoes Lane, Piscataway, NJ 08854-4141.

IEEE C2, National Electric Safety Code (NESC), 2017.

2.3.8 SAE Publications.

Society of Automotive Engineers SAE International , 400 Commonwealth Drive, Warrendale, PA 15096, www .SAE.org.

SAE J2600, Compressed Hydrogen Surface Refueling Connection Devices, 2012.

2.3.8 UL Publications.

Underwriters Laboratories, Inc., 333 Pfingsten Road, Northbrook, IL 60062-2096.

ANSI/ UL 723, Tests for Surface Burning Characteristics of Building Materials, 2008 , revised 2013 .

2.3.9 U.S. Government Publications.

U. S. Government Printing Government Publishing Office, 732 North Capitol Street, NW, Washington, DC 20402 20401-0001 .

Title 29, Code of Federal Regulations, Part 1910.1000.

2.3.10 Other Publications.

Merriam-Webster’s Collegiate Dictionary, 11th edition, Merriam-Webster, Inc., Springfield, MA, 2003.


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2.4 References for Extracts in Mandatory Sections.







NFPA 54, National Fuel Gas Code, 2015 edition.


NFPA 56, Standard for Fire and Explosion Prevention During Cleaning and Purging of Flammable Gas Piping Systems,2014 edition.



NFPA 80, Standard for Fire Doors and Other Opening Protectives, 2016 edition.


NFPA 88A, Standard for Parking Structures, 2015 edition.



NFPA 318, Standard for the Protection of Semiconductor Fabrication Facilities, 2015 edition.

NFPA 400, Hazardous Materials Code, 2016 edition.

NFPA 654, Standard for the Prevention of Fire and Dust Explosions from the Manufacturing, Processing, and Handling of Combustible Dust, 2013 edition.

NFPA 801, Standard for Fire Protection for Facilities Handling Radioactive Materials, 2014 edition.

NFPA 820, Standard for Fire Protection in Wastewater Treatment and Collection Facilities, 2016 edition.


NFPA 921, Guide for Fire and Explosion Investigations, 2015 edition.

NFPA 5000® , Building Construction and Safety Code®, 2015 edition.


Referenced current SDO names, addresses, standard names, numbers, and editions.

Related Public Inputs for This Document

Related Input Relationship

Public Input No. 5-NFPA 2-2016 [Chapter M]


Submitter Full Name: Aaron Adamczyk

Organization: [ Not Specified ]

Street Address:

City:

State:

Zip:

Submittal Date: Sat Jan 30 21:34:30 EST 2016


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Public Input No. 42-NFPA 2-2016 [ Section No. 2.3.1 ]



ANSI A13.1, Scheme for Identification of Piping Systems, 2007.

ANSI C2, National Electrical Safety Code, 2012.

ANSI /CSA FC 1, American National Standard for Fuel Cell Power Systems, 2012.

ANSI/CSA FC 3, American National Standard/CSA American Standard for Portable Fuel Cell Power Systems , 2004.



ANSI Z535.4, Product Safety Signs and Labels, 2011.


Remove CSA Group Reference Publications from 2.3.1 ANSI Publications. Proposal to recognize CSA Group as publisher of FC 1 & FC 3 has been submitted separately.



Public Input No. 313-NFPA 2-2016 [New Section after 2.3.4]


Submitter Full Name: sara marxen

Organization: CSA Group

Street Address:

City:

State:

Zip:



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ANSI A13.1, Scheme for Identification of Piping Systems , 2007.ANSI C2, National Electrical Safety Code, 2012.

ANSI/CSA FC 1, American National Standard for Fuel Cell Power Systems, 2012.

ANSI/CSA FC 3, American National Standard/CSA American Standard for Portable Fuel Cell Power Systems, 2004.



ANSI Z535.4, Product Safety Signs and Labels , 2011.

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2.

3.

.


Both of these documents were withdrawn.kj;lkj;k;j;lklkkj;kj;kjkjkjkj


Submitter Full Name: Jeanne Moreau-Correia

Organization: UL

Affilliation: NFSA

Street Address:

City:

State:

Zip:

Submittal Date: Tue Jun 14 12:40:34 EDT 2016


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American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959.

ASTM E84, Standard Test Method for Surface Burning Characteristics of Building Materials, 2014 2015 .


ASTM E1529, Determining Effects of Large Hydrocarbon Pool Fire on Structural Members and Assemblies, 2013 2014 .


ASTM E2652, Standard Test Method for Behavior of Materials in a Tube Furnace with a Cone-shaped Airflow Stabilizer, at 750°C, 2012.


Date updates


Submitter Full Name: Timothy Earl

Organization: GBH International

Street Address:

City:

State:

Zip:

Submittal Date: Mon Jan 04 11:46:39 EST 2016


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American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959.

ASTM E84, Standard Test Method for Surface Burning Characteristics of Building Materials, 2014 2015b .


ASTM E1529, Determining Effects of Large Hydrocarbon Pool Fire on Structural Members and Assemblies, 2013 2014a .


ASTM E2652, Standard Test Method for Behavior of Materials in a Tube Furnace with a Cone-shaped Airflow Stabilizer, at 750°C, 2012 2016 .


date updates


Submitter Full Name: Marcelo Hirschler


Street Address:

City:

State:

Zip:

Submittal Date: Sun May 15 17:16:05 EDT 2016


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Public Input No. 313-NFPA 2-2016 [ New Section after 2.3.4 ]

2.3.X CSA Group Publications. CSA Group, 8501 East Pleasant Valley Road, Cleveland, OH 44131.CSA B51, Boiler, pressure vessel, and pressure piping code, 2014.

ANSI/CSA FC 1, Fuel cell technologies – Part 3-100: Stationary fuel cell power systems – Safety, 2014.

ANSI/CSA America FC 3, Portable Fuel Cell Power Systems, 2004.


Move CSA FC 1 and FC 3 documents from 2.3.1 ANSI Publications section to a new section to recognize CSA Group as publisher of these documents. This proposal also updates CSA document designations, titles and/or year of edition. Also, add CSA B51 to the referenced publication list, as it is referenced in 3.3.193.



Public Input No. 42-NFPA 2-2016 [SectionNo. 2.3.1]

PI #42 removes CSA Group Standards from 2.3.1 ANSI Publications. PI #313 proposes to create new sectionfor CSA Group Publications.




Street Address:

City:

State:

Zip:



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2.3.7 SAE Publications.

Society of Automotive Engineers, 400 Commonwealth Drive, Warrendale, PA 15096, www.SAE.org.

SAE J2600, Compressed Hydrogen Surface Refueling Connection Devices, 2012.

SAE J2601, Fueling Protocols for Light Duty Gaseous Hydrogen Surface Vehicles

SAE J2799, Hydrogen Surface Vehicle to Station Communications Hardware and Software


These references are introduced in PI proposals for Section 10.3.1.13. SAE J2601 specifies fueling protocols for automotive dispensers. This standard has been developed by the automotive and hydrogen industry, to ensure that the fueling protocol will not overheat, over-pressurize or overfill the vehicle tank. SAE J2799 is a vehicle to dispenser fueling protocol used with SAE J2601 and most fuel cell vehicles on the road today


Submitter Full Name: Spencer Quong

Organization: Quong Associates Inc

Affilliation: Toyota

Street Address:

City:

State:

Zip:

Submittal Date: Mon Jun 27 17:07:26 EDT 2016


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ANSI/UL 723, Tests for Surface Burning Characteristics of Building Materials, 2008 2013 .


This updates the UL Standard to the current edition.


Submitter Full Name: Ronald Farr

Organization: UL LLC

Street Address:

City:

State:

Zip:



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ANSI/UL 723, Tests for Surface Burning Characteristics of Building Materials, 2008.

UL 252A, "Compressed Gas Regulator Accessories ,2010.

ANSI/UL 252, "Compressed Gas Regulators ,2010.


Reason Statement: 10.3.1.1 requires the listing or approval of various components. These standards identify the requirements and testing required for regulator and accessory listings and can be the basis for AHJ approval if not listed.


Submitter Full Name: Kelly Nicolello

Organization: UL llc

Street Address:

City:

State:

Zip:

Submittal Date: Wed Jun 29 08:40:04 EDT 2016


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Public Input No. 291-NFPA 2-2016 [ New Section after 3.3 ]

Standard Automotive Fueling ProtocolA procedure for fueling a hydrogen vehicle that was developed by an automotive industry standards organization

Non-Standard Automotive Fueling Protocol

A procedure for fueling a vehicle not developed by an automotive industry standards organization


These definitions are used in new PI proposals submitted for 10.3.1.13. It is important to specify fueling protocols designed by an automotive standard because it ensures that all vehicles can fuel at the dispenser without concerns of over heating, over-pressurization, or over-density. In addition, automotive companies have designed their vehicles around these standards.



Organization: Quong & Associates Inc


Street Address:

City:

State:

Zip:



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Hydrogen Equipment Court

Hydrogen equipment court. a court bounded on all sides by exterior walls that may include one or more walls of a building where permitted, and/or byexterior walls that must not exceed X-feet in height. THe court walls may support a protective weather shade or shield above process or storage equipmentbut must remain open on all sides at the top of the wall sufficient to allow for natural ventilation and mitigation or dispersion of any leaks. The court mustmeet all applicable prescriptive requirements for access entry and egress within, including lighting and electrical equipment. The court must meet anyprescriptive requirements in CGA P-41 where applicable. The court must be constructed to comply with the building code as required by the authority havingjurisdiction, and where required must specify a fire rating.


Input from NFPA-2 Technical Committee sub-group on HEE: The use of an enclosed court around pressurized gas storage equipment is prohibited in a number of sections in NFPA-55 [7.10.1.2.4] and [7.10.2.2.4], also prohibited for cryogenic storage, this creates a conflict with the as constructed walls around Hydrogen process equipment. The Hydrogen Equipment court is intended to meet the requirements for security and containment of the process and storage equipment, to provide a fire separation rating where required, and to meet the local aesthetic requirements of the community.

This change will rely on possible amendments to the CGA P-41 "Locating Bulk Storage Systems in Courts" to allow a 4-walled structure to surround Hydrogen process and storage equipment. We also submit that any changes should be verified by a safety and risk assessment such as testing or modeling to satisfy the proposed application is suitable to the intended design use. The TC should seek additional verification in coordination with NFPA-55 and the CGA Compressed Gas Association.


Submitter Full Name: Brian Ladds

Organization: Calgary Fire Department

Affilliation: NFPA-2 Technical Committee, HEE sub-group input

Street Address:

City:

State:

Zip:



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Public Input No. 67-NFPA 2-2016 [ New Section after 3.3.55.1 ]

3.3.56 CSA.

CSA Group.


CSA Group standards are referenced in the NFPA document, and should be included in the definitions. This proposal is similar to definitions that exist for ASME, ASTM and CGA.




Street Address:

City:

State:

Zip:

Submittal Date: Fri Jun 24 08:50:43 EDT 2016


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TITLE OF NEW CONTENT

ANNEX NOTE

2. Existing Text: Annex

A.3.3.117 Hydrogen Equipment Enclosure (HEE). Hydrogen equipment enclosures can include repurposed “shipping” or

“ISO” containers as defined in Section 3.3.8 of NFPA 307: A reusable, intermodal boxlike structure of rigid construction

fitted with devices to permit lifting and handling particularly

transfer from one mode of transportation to another mode of transportation.

Hydrogen equipment located in enclosures larger than the largest standard intermodal container (presently 56 ft long x

8 ft wide x 9.5 ft high) typically are subject to the requirements for indoor installations.

Hydrogen equipment enclosures include those used for equipment that process or store hydrogen.

Enclosures can be for weather protection, aesthetic treatment, security, or to prevent external damage.

Exterior enclosure walls are not typically intended to carry a fire resistance rating.

Enclosures can be enterable but are not intended to be occupied.

Hydrogen equipment in enclosures in laboratories are covered by Section 6.19.

(P.2) Proposed Changes:

A.3.3.117 Hydrogen Equipment Enclosure (HEE). Hydrogen equipment enclosures can include repurposed “shipping” or

“ISO” containers as defined in Section 3.3.8 of NFPA 307: A reusable, intermodal boxlike structure of rigid construction

fitted with devices to permit lifting and handling particularly transfer from one mode of transportation to another mode of

transportation.

Hydrogen equipment located in enclosures larger than the largest standard intermodal container (presently 56 ft long x

8 ft wide x 9.5 ft high) typically are subject to the requirements for indoor installations.



Exterior enclosure walls are not typically intended to carry a fire resistance rating .

The HEE may be designed to contain and control potential hydrogen leaks from hydrogen storage, compressors and other hydrogen fuel processingequipment, exterior walls may contain fire rating.


Hydrogen equipment in enclosures in laboratories are covered by Section 6.19.


Substantiation Statement: Exterior walls may indeed carry a fire resistance rating.

The Linde IC90 H70 fueling station in-a-box (HEE) system is a good example of this new proposed sentence. Powertech, Hydrogenics, H2 Logic and McPhy are also producing integrated systems that are fully enclosed and provide active mitigation of hydrogen leaks. Comments:

Sub-group comments: List looks good to go and should go into NFPA 2 and 55.





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3.3.117* Hydrogen Equipment Enclosure (HEE).

A prefabricated area designed to protect hydrogen system, device or appliance designed to contain hydrogen equipment that is confined by at least 3 walls

and a roof , not routinely occupied, and has a total area less than 450 ft2 (41.8 m2).


An “area” exists on a piece of land. We don't ship an area, we might ship an “appliance”, a “system”, “device” or an “appliance” that will then be located in, or installed into (per the building code) an area: this change is suggested for clarity.In the case where the H2 station designer has built four walls around an “area” where hydrogen equipment is located, the word “area” is very applicable We need to make a distinction between the two methods of reducing setbacks to H2 processing equipment

“and a roof” is three words that were somehow removed from the definition at the last minute in error. There may be some confusion, but most NFPA-2 technical Committee members know there should be “and a roof” in this definition and that the omission of these three word was and error.

“Protection” is not as descriptive as “contain”. Protection could be weather protection NFPA2:6.6 and this ambiguity is cleaned up with the change from “protect” to “contain”. HEEs may contain just the hydrogen equipment but may also contain hydrogen leaks and vent any leaks to a safe location and use the containment as a method detect and manage hydrogen leaks.

Comments: Submit to Technical committees for 2 and 55





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Public Input No. 138-NFPA 2-2016 [ Section No. 4.2.3.1.2.5 ]

4.2.3.1.2.5*

Operations shall be conducted at facilities in a safe manner that minimizes, reduces, controls, or mitigates the risk of fire injury or death for the operators,while protecting the occupants not intimate with initial fire development for the amount of time needed to evacuate, relocate, or defend in place.[1:4.1.3.1.2.5]


“safe” a subjective and redundant adjective which is not actionable in this context.


Submitter Full Name: William Collins

Organization: WPC Sol LLC

Street Address:

City:

State:

Zip:

Submittal Date: Sun Jun 26 17:23:14 EDT 2016


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Public Input No. 139-NFPA 2-2016 [ Section No. 4.3.1.1 ]

4.3.1.1

The fire protection methods of this code shall assume multiple unrelated simultaneous fire incidents will not occur. [ 1: 4.2.1.1]


We need to account for cascade failures.




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4.3.1.2

The single fire source assumption shall not preclude the evaluation of multiple unrelated design fire scenarios as required by Section 5.4. [1:4.2.1.2]


We need to account for cascade failures.




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4.4.3 Where any of the requirements of either compliance method requires records to be kept they shall comply with the following:

(A) Records shall be maintained on the premises or other approved location.

(B) Retention of records onsite shall be for not less than 3 years, or shall comply with the period of time where specified in this code or referencedstandards, whichever is longer.

(C) Records shall be made available for inspection by the AHJ and a copy shall be provided to the AHJ upon request.


Reason: The purpose of this proposal is to establish standard rules for the keeping of records. If the committee agrees with this direction and approves the suggested language, the next step will be to review NFPA 2 and where ever a requirement for a record is mentioned a pointer to this new section would be added.


Submitter Full Name: Robert Davidson

Organization: Davidson Code Concepts, LLC

Affilliation: Quong & Associates, Inc./Toyota USA

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4.6.2

The plan shall be available for inspection by the AHJ and shall include the following information:

(1) The type of emergency equipment available and its location

(2) A brief description of any testing or maintenance programs for the available emergency equipment

(3) An indication that hazard identification labeling is provided for each storage area

(4) The location of posted emergency procedures

(5) A material safety safety data sheet (MSDS SDS ) or equivalent for GH2 or LH2 stored or used on the site

(6) A list of personnel who are designated and trained to be liaison personnel for the fire department and who are responsible for the following:

(7) Aiding the emergency responders in pre-emergency planning

(8) Identifying the location of the GH 2 and LH 2 stored or used

(9) Accessing MSDSs

(10) Knowing the site emergency procedures

(11) A list of the types and quantities of GH2 and LH2 found within the facility


US DoL OSHA changed the terminology. Please convert to be consistent with OSHA




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4.10.1* Prohibited Releases.

[GH 2 or LH 2 ] shall not be released into a sewer, storm drain, ditch, drainage canal, lake, river, or tidal waterway; upon the ground, sidewalk, street, or

highway

unless such release is permitted by the following: [ 400: 6.1.3.1].

The following exceptions are permitted:

(1) Federal, state, or local governing regulations [400:6.1.3.1(1)]

(2) Permits of the jurisdictional air quality management board [400:6.1.3.1(2)]

(3) National Pollutant Discharge Elimination System Permit [400:6.1.3.1(3)]

(4) Waste discharge requirements established by the jurisdictional water quality control board [400:6.1.3.1(4)]

(5) Sewer pretreatment requirements for publicly owned treatment works [400:6.1.3.1(5)]

(6) Pressure relief devices and vents designed as part of a system


The grammar is convoluted and may lead to error. The proposed modification, which includes a new one line paragraph is an attempt to minimize the potential confusion.




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[GH2 or LH2] shall not be released into a sewer, storm drain, ditch, drainage canal, lake, river, or tidal waterway; upon the ground, sidewalk, street, or

highway unless such release is permitted by the following: [400:6.1.3.1]


(2) Permits of the jurisdictional air quality management board [ 400: 6.1.3.1(2)]

(3)

(4) National Pollutant Discharge Elimination System Permit [400:6.1.3.1(3)]

(5) Waste discharge requirements established by the jurisdictional water quality control board [400:6.1.3.1(4)]

(6) Sewer pretreatment requirements for publicly owned treatment works [400:6.1.3.1(5)]



This requirement is for hazardous material that are toxic to the air. such gases are CO2, Methane, Ethane, Volatile Organic Compounds (VOCs) hydrocarbons, fluorocarbons, and the list goes on and on, but hydrogen is not on that list of toxic gases. hydrogen is breathable up to 10 % in air although flammable, not a greenhouse gas and does not present any chemical threat to the environment as hydrogen gas or liquid or as a product of combustion; water.

Air quality management boards want H2 motor fuel projects in their jurisdictions because there is a net reduction in greenhouse.

delete this requirement from NFPA 2.


Submitter Full Name: Robert Boyd

Organization: Boyd Hydrogen LLC

Affilliation: Boyd Hydrogen LLC

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[GH2 or LH2] shall not be released into a sewer, storm drain, ditch, drainage canal, lake, river, or tidal waterway; upon the ground, sidewalk, street, or

highway unless such release is permitted by the following: [400:6.1.3.1]


(2) Permits of the jurisdictional air quality management board [400:6.1.3.1(2)]

(3) National Pollutant Discharge Elimination System Permit [ 400: 6.1.3.1(3)]

(4) Waste discharge requirements established by the jurisdictional water quality control board [ 400: 6.1.3.1(4)]

(5) Sewer pretreatment requirements for publicly owned treatment works [ 400: 6.1.3.1(5)]

(6)



These requirements are for hazardous materials that are toxic to waterway.

These are all concerning releases that could contaminate waterways. The National Pollutant Discharge Elimination System, waste water discharge regulations, and sewer treatment system requirements do not apply to hydrogen releases and are targeted at liquids that can run off a site and mix with water such as Material handling and storage of bulk solids or liquids that can spill, equipment maintenance and cleaning, and other activities at industrial facilities that are often exposed to the weather. Runoff from rainfall or snowmelt that comes in contact with these activities can pick up pollutants, and transport them directly to a nearby river, lake, or coastal water or indirectly via a storm sewer and degrade water quality.

Even if Liquid hydrogen was spilled in massive quantities, there would no chemical or toxicity implications if the release contacted water event directly and all liquid hydrogen turns to hydrogen vapor which rises quickly into the atmosphere.

Hydrogen is not a potential contaminate of waterways, these requirements are not applicable to hydrogen (gas or liquid)



Organization: Boyd Hydrogen LLC

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4.10.6.1

The person, firm, or corporation responsible for an unauthorized release of a hazardous process material (e.g. catalyst, heat transfer fluid, lubricant,etc.) shall institute and complete all actions necessary to remedy the effects of such unauthorized release, whether sudden or gradual, at no cost to theAHJ. [ 400: 6.1.3.7.1]


There is no cleanup of hydrogen. It disperses. However, there may be process materials which require cleanup. Some of these materials may be toxic and/or pyrophoric.




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4.10.6.2

When deemed necessary by the AHJ, cleanup of an unauthorized release of a process material (e.g. catalyst, heat transfer fluid, lubricant, etc.) shall bepermitted to be initiated by the fire department or by an authorized individual or firm, and costs associated with such cleanup shall be borne by the owner,operator, or other person responsible for the unauthorized release. [ 400: 6.1.3.7.2]


Again, there is no cleanup of hydrogen. It disperses. However, there may be process materials which require cleanup. Some of these materials may be toxic and/or pyrophoric.




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4.11.1.2 Hazard Communications.

Training shall be provided prior to beginning work in the work area to enable personnel to recognize and identify [GH2 or LH2] hydrogen stored,

dispensed, handled, or used on site and where to find hazard safety information Safety Data Sheets pertaining to all the materials employed .[ 400: 6.1.4.1.2] on the station for the generation, processing and dispensing of hydrogen; including hydrogen.


US DoL OSHA changed the terminology. Please convert to be consistent with OSHA

There may be process materials which are hazardous. Some of these materials may be toxic and/or pyrophoric.




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Public Input No. 148-NFPA 2-2016 [ Section No. 4.11.2 [Excluding any Sub-Sections] ]

Persons engaged in the generation, processing, storing, using, or or handling [GH2 or LH2] hydrogen on site shall be designated as operations personnel

and shall be trained in accordance with 4.11.1 and 4.11.2.1 through 4.11.3.2. [ 400: 6.1.4.2]


There may be on site generation, cleanup (e.g. pipeline odorants). We should avoid the term using because it may be considered synonymous with dispensing of hydrogen fuel.




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Persons engaged in storing, using, or handling [GH2 or LH2] shall be designated as operations personnel and shall be trained in accordance with 4.11.1

and 4.11.2.1 through 4.11.3.2. [400:6.1.4.2]

New Section after 4.11.2:

4.11.2.1 Persons performing public motor fuel dispensing of GH2 Vehicles in accordance with Chapter 10 shall not be designated as operations personneland shall not be subject to the requirements of 4.11.2.

Renumber subsequent sections.


A literal application of existing requirement could result in a requirement to train members of the public who are simply refueling their GH2 powered vehicle beyond the simple requirements of 4.11.1 which can be addressed mostly by signage for a refueling operation. For a public fueling station in compliance with Chapter 10, the need for additional training of public personnel is minimal - similar to how gasoline is handled.


Submitter Full Name: Martin Gresho

Organization: Fp2fire Inc

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4.11.2.2 Dispensing, Using, and Processing.

Operations personnel shall be trained in the specific safeguards applicable to the dispensing to all facets of generation , processing, or use storing, andhandling of the materials and the equipment employed . [ 400: 6.1.4.2.2] for that specific site.


Different sites may have different system designs and/or hardware. Therefore the hazards may be different requiring specific training requirements,




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4.11.2.3 Storage system .

Operations personnel shall be trained in the application of storage system arrangements and site-specific limitations on storage for the materials employed.[400:6.1.4.2.3]


The proposed change is to eliminate confusion (either actual or professed) by the user of this document. In discussions with Ms. Quakenbush, it was determined that compression, if used, will most likely be co-located with storage and should be considered integral with the storage system. However, who are versed in this and other relevant documents took several minutes looking for the clarification. Thus we believe that modifying “storage” to “storage system” will lead the user to the definitions in 3.3.227, which while not overly specific, highly infer compression to be part of a storage system.




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4.11.3.2

Emergency response liaison personnel shall do the following:

(1) Aid emergency responders in pre-planning responses to emergencies

(2) Identify locations where [GH2 or LH2] are located

(3) Have access to material safety data sheets

(4) Be knowledgeable in the site emergency response procedures

[400:6.1.4.3.2]


US DoL OSHA changed the terminology. Please convert to be consistent with OSHA and section 4.9.3




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4.11.4.5 Documentation.

4.11.4.5.1 Training documents shall conform in format and symbology to US DoL OSHA regulations (i.e. be in compliance with the NEMAZ535 series of documents)

4.11.4.5.2 Training shall be documented and made available to the AHJ upon written request.

[ 400: 6.1.4.6]


There are two embedded requirements in this clause that should be clear. Therefore split the clause.

The first is a federal requirement, the documents shall conform to ANSI/NEMA Z535. There are repeated references in 23 CFR 1910 (e.g. 1910.145). As an aside, please note that ANSI/NEMA documents are heavily harmonized with their ISO counterpart, but they are not identical

The second change is a new clause number for the existing text.




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4.12.2 Open Flames and High-Temperature Devices.

4.12.2.1 Open flames and high-temperature devices shall not be used in a

manner that creates a hazardous condition. [ 400: 6.1.5.2]classified area as defined in NFPA 70 Articles 500 thru 505 without a hot work permit and safety procedures stipulate in the permit being in effect.

4.12.2.2 High-temperature devices used in a classified area as defined in NFPA 70 Article 501 shall not exceed 80% of the auto-ignitiontemperature on a degree C basis for the fluids which result in the classification. The auto-ignition temperature value used is stipulated in NFPA 497.

The selections and installation high temperature device shall be conformance with any additional requirements stipulated in NFPA 70 Articles 500thru 505.


The proposed change is to eliminate confusion (either actual or professed) by the user of this document. The original text is, in our opinion, incomplete and non-actionable to the novice. The amended text is an attempt to clearly define requirements and point the user to the appropriate requirements in NFPA 70.




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4.13.1.1 Design and Construction.

Signs shall be durable, and the size, color, and lettering of signs shall be in accordance with nationally recognized standards . [ 400: 6.1.8.1.1] ( e.g. theNEMA Z535 series of documents) .


The first is a federal requirement, the documents shall conform to ANSI/NEMA Z535. There are repeated references in 23 CFR 1910




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4.14.1.1

Guard posts4.14.1.1 Bollards or other approved means shall be provided to protect the following where

subject tothere is the potential of vehicular damage:

Storage tanks and connected(1) * Containment system including but not limited to storage, compression, interconnecting piping, valves, and fittings

(2) Storage areas containing tanks or portable containers except where the exposing vehicles are powered industrial trucks used fortransporting the [

GH 2GH2 or

LH 2LH2 ] hydrogen

(3) Use areas

[ 400: 6.1.9.1]


First the guard post is called a bollard. A guard post is where a sentry is.

“A bollard is a short vertical post. Originally it meant a post used on a ship or a quay, principally for mooring. The word now also describes a variety of structures to control or direct road traffic, such as posts arranged in a line to obstruct the passage of motor vehicles.”

Second, the phrasing was incosistant




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5.1.5* Independent Review.

The AHJ shall be permitted to requireIf the AHJ requires an approved, independent third party to review the proposed design and provide an evaluation of the design

tofor the AHJ at the expense of the owner.

[ 1: 5.1.5]


The AHJ already has this authority, do not allow the user the misconception that this is open to discussion.




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6.2.1 In seismically active areas, designs shall include the seismic design requirements of the [adopted] building code.


Reason: The proposed language points the user to the [adopted] building code where the seismic zones and requirements are addressed to ensure designs and installations address seismic requirements.





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6.4.1 Quantity Thresholds for GH2 or LH2 Requiring Special Provisions.

6.4.1.1 Threshold Exceedences.

Where the quantities of [GH2 or LH2] stored or used within an indoor control area exceed those shown in Table 6.4.1.1, the area shall meet the

requirements for [the occupancy classification] in accordance with the [adopted] building code, based on the requirements of 6.4.2. [55:6.3.1.1]

Table 6.4.1.1 Maximum Allowable Quantity of Hydrogen per Control Area (Quantity Thresholds Requiring Special Provisions)

UnsprinkleredAreas Sprinklered Areas Material

No Gas Cabinet, GasRoom, or Exhausted

Enclosure

Gas Cabinet, GasRoom, or Exhausted

Enclosure

No Gas Cabinet, GasRoom, or Exhausted

Enclosure

Gas Cabinet, GasRoom, or

ExhaustedEnclosure

LH2 0 gal (0 L)45 gal(170 L) †

45 gal(170 L)

45 gal(170 L)

GH21000 ft3

(28 m3)

2000 ft3

(56 m3)

2000 ft 3

(56 m 3 )

4000 ft 3

(112 m 3 )

Note: The maximum quantity indicated is the aggregate quantity of materials in storage and use combined.

†A gas cabinet or exhausted enclosure is required. Pressure relief devices or stationary or portable containers shall be vented directly outdoors or to anexhaust hood. (See 8.1.4.6.)

6.4.1.2 Aggregate Allowable Quantities.

The aggregate quantity in use and storage shall not exceed the quantity listed for storage. [55:6.3.1.3]

6.4.1.3 Incompatible Materials.

When the classification of materials in individual containers requires the area to be placed in more than one [occupancy classification], the separation of[occupancies] shall not be required, providing the area is constructed to meet the requirements of the most restrictive [occupancy classification] and that theincompatible materials are separated as required by 7.2.1.1. [55:6.3.1.4]

6.4.1.4 Multiple Hazards.

GH2 blended with other gases having multiple hazards shall also comply with NFPA 55.

6.4.1.5 GH2.

6.4.1.5.1*

[GH 2 ] shall not be stored or used in other than industrial and storage occupancies. [ 55: 6. 3.1.6.1]

6.

4.1.5.1.1

Cylinders, containers, or tanks not exceeding 250 scf (7.1 Nm3) content at normal temperature and pressure (NTP) and used for maintenance purposes,patient care, or operation of equipment shall be permitted. [ 55: 6.3.1.6.2]

6.4.1.5.1.2

Piping systems used to supply GH2 in accordance with 7.1.15.1 shall be permitted.


Table 6.4.1.1

I’m having heartburn with requiring sprinkler systems.

This requirement makes since for compressed gas cylinders containing non-flammable gases. He concern apparently being addressed is the cylinder “cooking off” during a structural fire. “Cooking off” is caused by overheating the cylinder without the temperature actuated PRD (CGA S-1 valve) actuating.

This is a real concern. Most cylinders are made from UNS G4130. This material is limited to 650oF. Above that temperature the quickly loses strength. Most alloy steels have lost 90% of their strength before reaching 1000oF.

However, for a fuel gas in a cylinder (hydrogen, natural gas, etc.) a more common concern would be a release due to a defective PRD (CGA S-1 valve), a damaged or defective cylinder valve (CGA V-1 valve), and/or a leaking attachment. In this case, a sprinkler system is not necessarily a wise move. I’ve was taught that when dealing with fuel gas fires, isolate the source of the gas and allow the gas to be consumed prior to fighting a secondary fire (in this case a structural fire would be a secondary fire). If the fuel fire is extinguished prior to removal of the source, this will result in the risk of re-ignition and the potential for an explosion.

How should we proceed to resolve the issue? Punting is not recommended.

6.4.1.5 Seriously, we can’t use gaseous hydrogen in a laboratory, as a motor fuel, as a fuel gas.6.4.1.5.1.1 Patient care is not a viable option. What about commercial or residential power generation? Commercial handling equipment, like stackers? How about laboratory applications? Let’s not go there.




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6.4.1.5 GH 2 Gaseous Hydrogen .

6.4.1.5.1*

[GH2] shall not be stored or used in other than industrial and storage occupancies. [55:6.3.1.6.1]

6.4.1.5.1.1

Cylinders, containers, or tanks not exceeding 250 scf (7.1 Nm3) content at normal temperature and pressure (NTP) and used for maintenance purposes,patient care, or operation of equipment shall be permitted. [55:6.3.1.6.2]

6.4.1.5.1.2



Editorial. Since this is a heading I prefer spelling out the acronym here.




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6.4.1.5 GH2.

6.4.1.5.1*

[GH 2 ] shall not be stored or used in other than industrial and storage occupancies. [ 55: 6.3.1.6.1]

6.4.1.5.1.1

Cylinders, containers, or tanks not exceeding 250 scf (7.1 Nm3) content at normal temperature and pressure (NTP) and used for maintenance purposes,patient care, or operation of equipment shall be permitted. [55:6.3.1.6.2]

6.4.1.5.1.2



Seriously, we can’t use gaseous hydrogen in a laboratory, as a motor fuel, as a fuel gas .

Patient care is not a viable option. What about commercial or residential power generation? Commercial handling equipment, like stackers? How about laboratory applications?




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Public Input No. 387-NFPA 2-2016 [ Section No. 6.4.1.5.1 [Excluding any Sub-Sections] ]

[GH 2 ] shall not be stored or used in other than industrial and storage occupancies. [ 55: 6.3.1.6.1]


This section is overly restrictive and presents a road block to hydrogen technology. A simple example is use of hydrogen in a laboratory which is classified as either a business or educational occupancy. This topic is best regulated by the adopted building and fire codes which include thresholds for varied levels of protection.



Public Input No. 388-NFPA 2-2016 [Section No. A.6.4.1.5.1]





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6.4.1.5.1.1

Cylinders, containers, or tanks not exceeding 250 scf (7.1 Nm3) content at normal temperature and pressure (NTP) and used for maintenance purposes,patient care, [-] or operation of equipment shall be permitted. [55:6.3.1.6.2]


Hydrogen is not needed for patient care. The target gas here is oxygen in NFPA 55 so deleting "patient care" here makes NFPA 2 more applicable to hydrogen only. I prefer to retain the extract tag to NFPA 55 so the bracket approach has been utilized to signify editorial changes made to make the text applicable to hydrogen. The use of the bracket approach is consistent with the 2nd paragraph of the introductory text on page 2-1 of 2016 NFPA 2 and pasted here for convenience.

Text from 2015 NFPA 2 page 2-1....This code is largely extracted from other NFPA codes and standards (e.g., NFPA 52,NFPA 55, and NFPA 853) and is organized in a fashion that is specific for hydrogen. Paragraphsthat have been extracted from other documents are shown with the extract referencebrackets [] at the end of the paragraph. In some cases, modifications have been made to theextracted text to use terminology appropriate for this code, such as the terms GH2 instead ofcompressed gas and LH2 instead of cryogenic fluid. In those instances, brackets [] encase themodifying words. Similarly, where language was deleted to adhere to requirements basedexclusively on hydrogen and no other changes were made to the paragraph, brackets thatencompass a dash [-] are inserted into the paragraph to denote a change to the originalmaterial while retaining the extract to the source document. In short, added or modified textis shown with [] around the differing language and pure deletions of text are shown as [-].



Organization: FP2FIRE, Inc

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6.6.1.4

Buildings or structures used for weather protection shall be in accordance with the following:

(1) The building or structure shall be constructed of noncombustible materials.

(2) Walls shall not obstruct more than one side of the structure unless ventialted and/or employing blow out panels .

(3) Walls shall be permitted to obstruct portions of multiple sides of the structure, provided that the obstructed area does not exceed 25 percent of thestructure’s perimeter area.

(4) The building or structure shall be limited to a maximum area of 1500 ft2 (140 m2), with increases in area allowed by the building code based onoccupancy and type of construction.

(5) The distance from the structure constructed as weather protection to buildings, lot lines, public ways, or means of egress to a public way shall not beless than the distance required for an outside hazardous material storage or use area without weather protection based on the hazard classification ofthe materials contained.

(6) Reductions in separation distance shall be permitted based on the use of fire barrier walls where permitted for specific materials in accordance withthe requirements of Chapters 7 and 8.

[55:6.6.3]


The use of ventilation and blow out panels should be allowed to enclose the structure.




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6.7.1.2 When standby power is required, the system shall meet the requirements for a Level 2 system in accordance with NFPA 111.


Reason: NFPA currently has NFPA 55 extract guidance for what level system should apply when emergency power is required. The purpose of this proposal is to provide matching language providing guidance for what level system should apply if a standby power system is installed.

Background

NFPA 110

4.4* Level. This standard recognizes two levels of equipment installation, performance, and maintenance.

4.4.1* Level 1 systems shall be installed where failure of the equipment to perform could result in loss of human life or serious injuries.

4.4.2* Level 2 systems shall be installed where failure of the EPSS to perform is less critical to human life and safety.

NFPA 111

4.5* Level. The level of equipment installation, performance, and maintenance shall be as specified in 4.5.1 through 4.5.5.

4.5.1* Level 1 systems shall be installed where failure of the equipment to perform could result in loss of human life or serious injuries.

4.5.2* Level 2 systems shall be installed where failure of the EPSS to perform is less critical to human life and safety.





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6.7.2 Emergency Power.

When emergency power is required, the system shall meet the requirements for a Level 2 system in accordance with NFPA 110 . [ 55: 6.7.2] and/or NFPA111.


Why isn’t NFPA 111 mentioned?




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6.14.3* LH2. Diking or berms shall be used when necessary to direct the spill away from an additional hazard.

A.6.14.3 The site design for liquid hydrogen storage shall prevent pooling of the leak, but may use berms or dikes to redirect a spill away from stormsewers, building access points or other hazards and to direct the release to an appropriate area.


Reason: The purpose of this proposal is to add language dealing with the use of diking or berms to redirect flow from an LH2 leak away from an identified additional hazard.





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6.14.2 LH2.

Diking shall not be used to contain an [LH 2 ] spill. [ 55: 11.3.1.2]

The site design for liquid hydrogen storage shall prevent pooling of the leak, but may use berms or dikes to redirect a spill away from an additionalhazard.


We should allow berms or dikes to direct the release to an appropriate area and avoid storm sewers, building access points, etc. We should prevent pooling. This is not clear in this statement.




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Public Input No. 346-NFPA 2-2016 [ Section No. 6.15 ]

6.15 Shelving.

6.15.1

Shelves used for the storage of cylinders, containers, and tanks shall be of noncombustible substantial construction consisting of noncombustible materials and designed to support the weight of the materials stored. [ 55: 6.14.1]

6.15.2

In seismically active areas, shelves and containers shall be secured from overturning. [ 55: 6.14.2] shelving shall be braced and anchored in accordancewith the seismic design requirements of the [adopted] building code .


Reason: The purpose of this change to is clarify that substantial construction should always be employed where the storage of cylinders, containers and/or tanks are involved regardless of seismic activity. The language addressing seismic protection is modified to point the user to the [adopted] building code where the seismic zones and requirements are addressed.





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6.15.2

In seismically active areas, shelves and containers Shelves used for the storage of equpment and and containers (e,g, cylinders, vessels) shall be securedfrom overturning. [ 55: 6.14.2]


200 scft cylinders like the 3AA2015, weigh in excess of 100 lbs. Inadvertently dropping one on the cylinder valve will ruin someone’s day. Don’t limit the requirement to seismically active areas.




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Vent Pipe Termination

6.16.1 The vent exit elevation shall be a minimum of 10 ft (3 m) above grade; or 2 ft (0.61 m) above adjacent equipment; or 5 ft (1.5 m) aboverooftops. 6.16.2 The exits of vent stacks shall be located so the concentration of vented gas at any point of personnel exposure is below the flammable orasphyxiation limit. Exits of vent stacks shall be located outdoors and away from personnel areas, ignition sources, air intakes, building openings,and overhangs.


Reason: Questions have routinely arisen when dealing with the location of vent pipe terminations and the locations for defueling discharges. The typical path is from a model building and fire code to NFPA 2 which then refers to CGA-G-5.5 to find guidance. The current language in NFPA 2 for vent pipe termination at 7.1.17.3.2 points the user back to Section 6.16 and for defueling discharge the user is pointed to Section 18.7.

To provide more affirmative language within NFPA 2 dealing with the location of the termination and discharge points language is proposed to be added to 6.16 and 18.7.5. The language is sourced from CGA-G-5.5 and by placing it within the body of NFPA 2 it helps the user of the code to design and install compliant systems as well as assists code officials by providing clear guidance.

Along with the proposed changes to 6.16 and 18.7.5, a new Annex note “A.18.7.5” is proposed to point back to the guidance found at annex note A.6.16.

Related

A.6.16 The termination point for piped vent systems serving cylinders, containers, tanks, and gas systems used for the purpose of operational or emergency venting [should] be located to prevent impingement exposure on the system served and to minimize the effects of high temperature thermal radiation or the effects of contact with the gas from the escaping plume to the supply system, personnel, adjacent structures, and ignition sources. [55:6.15]

7.1.17.3 Vent Pipe Termination.

7.1.17.3.1 Venting of [GH2] shall be directed to an approved location. [55:7.3.1.5.1]

7.1.17.3.2 The termination point for piped vent systems serving cylinders, containers, tanks, and gas systems used for the purpose of operational or emergency venting shall be in accordance with Section 6.16. [55:7.3.1.5.2]

18.3 General.

18.3.1 Motor Vehicle Repair Areas. Repairing of motor vehicles shall be restricted to areas specifically provided for such purposes. [30A:9.7.1]

18.3.1.1 The discharge or defueling of hydrogen from fuel supply containers shall be required for the purpose of fuel storage system modification or repair or when welding or open flame activities occur within 18 in. (0.45 m) of the vehicle fuel supply container. Defueling shall be in accordance with Section 18.7.

18.3.1.2 Other than for those repairs listed in 18.3.1.1, repairs that would be required to be performed in a major repair garage shall be permitted to be performed in a minor repair garage if the vehicle is defueled in accordance with Section 18.7 to less than 200 scf (5.7 Nm3) and the fuel supply container is sealed.

18.7 Defueling Systems.

18.7.1 Methods of Discharge. The discharge of hydrogen from motor vehicle fuel storage tanks shall be accomplished through an approved method of atmospheric venting in accordance with 18.7.1 through 18.7.6.

18.7.2 Defueling Equipment Required at Vehicle Maintenance and Repair Facilities. Major repair garages shall have equipment to defuel vehicle fuel supply containers. Equipment used for defueling shall be listed and labeled for the intended use.

18.7.3 Manufacturer Equipment Required. Equipment supplied by the vehicle manufacturer shall be used to connect the vehicle fuel supply containers to be defueled to the defueling system.

18.7.4 Isolated Use. The defueling shall not be connected to another venting system used for any other purpose.

SourceCGA G5.5-2014

6.2.4 Discharge of warm gasHigh exit velocities in a vertically released vent and the low density of warm, gaseous hydrogen in relation to air will aid in its dispersion and dilution in the atmosphere. The vent exit elevation should be the greater of the elevation determined in 6.2.3 or 10 ft (3 m) above grade; or 2 ft (0.61 m) above adjacent equipment; or 5 ft (1.5 m) above rooftops.

6.2.8 Vent locationsThe exits of vent stacks shall be located so the concentration of vented gas at any point of personnel exposure is below the flammable or asphyxiation limit. Exits of vent stacks shall be located outdoors and away from personnel areas, ignition sources, air intakes, building openings, and overhangs. The siting distances from exposures specified in NFPA 55. required by the authority having jurisdiction (AHJ) or local fire code requirements, as applicable, can be used as general guidelines to locate vent stacks for hydrogen user locations [4].



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6.17.2 Mechanical Exhaust Ventilation.

*The mechanical exhaust ventilation system shall draw (not push) air from the ventilated volume in which hydrogen is being used.

A6.17.2 For lighter than air flammable gases, pressurizing the ventilated volume results in the storage of and potentially the uncontrolled leakage of anyinadvertent releases within the ventilated volume. The uncontrolled leakage would be due to penetrations of and insufficient sealing of the ventilatedvolume perimeter. Operating the enclosed space, sub ambient results in the exhausting of the inadvertent releases through a known point in the ventilatedvolume perimeter, minimizing the possibility of accumulation of a flammable gas within and avoiding uncontrolled leakage randomly from the ventilatedvolume perimeter.

The mechanical exhaust ventilation system hardware shall be suitable for use within the area classification (NFPA 70 Article 500-505) of the ventilatedvolume.


For many products using mechanical ventilation, the classified area within an enclosure is held at a sub-ambient pressure. This is a variation of NFPA 496. The non-classified area is held at ambient or above resulting in positive pressurization relative to the potentially classified area.

The proposed clause attempts to address this successful technique.




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6.17.2 Repair Garages

Repair garages for hydrogen vehicles shall meet the requirements in Chapter 18.


This PI moves the repair garage exhaust requirements to Chapter 18. This is important because Chapter 18 is being aligned with NFPA30A and IFC to encourage the same exhaust requirement for all repair garages. This proposal should only be considered if PI 151 is accepted.



Public Input No. 151-NFPA 2-2016 [Section No. 18.4] Only consider PI 413 is PI 151 is approved





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6.17.1 Ventilation Rate.

Mechanical exhaust or fixed natural ventilation shall be at a rate of not less than 1 scf/min/ft2 (0. 3048 Nm 0051 m 3 / min/ s · m 2 ) of floor area over thearea of storage or use. [55:6.16.3.2]


This should be easy. The metric units are supposed to be in SI units. SI doesn’t use minutes; only hours or seconds as defined in ANSI SI-10.

IFC2012 608.6.1 - .2 Continuous ventilation shall be provided at a rate of not less than 1 cubic foot per minute per square foot (1 ft3/min/ft2) [0.0051 m3/s · m2] of floor area of the room.




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Public Input No. 358-NFPA 2-2016 [ Sections 6.17.1, 6.17.2 ]

Sections 6.17.1, 6.17.2

6.17.1 Ventilation Rate.

Mechanical exhaust or fixed natural ventilation shall be at a rate of not less than 1 scf/min/ft2 (0.3048 Nm3/min/m2) of floor area over the area of storage oruse. [ 55: 6.16.3.2] , but no less than 1 ft3/min/12 ft3 (0.03 m3 /min/0.34 m3) of room volume .

6.17.2 Mechanical Exhaust Ventilation.

6.17.2.1 Ventilation Systems.

In addition to the requirements of Section 6.17, ventilation systems shall be designed and installed in accordance with the requirements of the [adopted]mechanical code. [55:6.16.2]

6.17.2.1.1 Continuous Operation.

When operation of ventilation systems is required, systems shall operate continuously unless an alternative design is approved by the AHJ. [55:6.16.3.1]

6.17.2.1.2 Shutoff Controls.

Where powered ventilation is provided, a manual shutoff switch shall be provided outside the room in a position adjacent to the principal access door to theroom or in an approved location. [55:6.16.5]

6.17.2.1.3 Manual Shutoff Switch.

The switch shall be the breakglass or equivalent type and shall be labeled as follows:

WARNING:

VENTILATION SYSTEM EMERGENCY SHUTOFF

[55:16.3.3.1]

6.17.2.1.4 Inlets to the Exhaust System.

6.17.2.1.4.1

The exhaust ventilation system design shall take into account the density of the potential gases released. [55:6.16.4.1]

6.17.2.1.4.2

For gases that are lighter than air, exhaust shall be taken from a point within 12 in. (305 mm) of the ceiling. The use of supplemental inlets shall be allowedto be installed at points below the 12 in. (305 mm) threshold level. [55:6.16.4.3]

6.17.2.1.4.3*

For [LH2 systems], exhaust shall be taken from a point within 12 in. (305 mm) of the floor. The use of supplemental inlets shall be allowed to be installed at

points above the 12 in. (305 mm) threshold level. [55:6.16.4.2]

6.17.2.1.5 Recirculation of Exhaust.

The location of both the exhaust and inlet air openings shall be designed to provide air movement across all portions of the floor or ceiling of the room orarea to prevent the accumulation of [hydrogen] within the ventilated space. [55:6.16.4.4]

6.17.2.1.6 Ventilation Discharge.

Ventilation discharge systems shall terminate at a point not less than 50 ft (15 m) from intakes of air-handling systems, air-conditioning equipment, and aircompressors. [55:6.16.6]

6.17.2.1.7 Air Intakes.

Storage and use of GH2 or LH2 shall be located not less than 50 ft (15 m) from air intakes.

The air inlets shall be designed to prevent foreign matter from entering. Air intakes to a hydrogen generation system shall be located so the plant is notadversely affected by other exhausts, gases, or contaminants.


Reason: In reviewing NFPA 2 the general requirements for ventilation exhaust systems is found at Section 6.17. The core requirements of system design and installation are located in 6.17 including a link to the requirements of the [adopted] mechanical code.

In following sections of NFPA where ventilation is required, most point to Section 6.17, some repeat similar requirements, some set up potentially conflicting requirements and some add additional requirements specific to the type of installation requiring the exhaust ventilation.

This proposal is intended to correlate the various exhaust ventilation requirements by adding some of the later design material to Section 6.17 to enhance the core design parameters, adding pointers to Section 6.17 where lacking, deleting overlapping or otherwise unnecessary language and leaving additional requirements specific to the type of system ventilated in those areas of NFPA 2.



Public Input No. 359-NFPA 2-2016 [New Section after A.6.17]

Public Input No. 361-NFPA 2-2016 [Sections 7.1.23.10.2, 7.1.23.10.3]

Public Input No. 362-NFPA 2-2016 [Section No. 7.3.2.2.2.2]

Public Input No. 363-NFPA 2-2016 [Section No. 8.1.15.2]





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Public Input No. 373-NFPA 2-2016 [Sections 10.3.3.2.2(F), 10.3.3.2.2(G), 10.3.3.2.2(H)]


Public Input No. 377-NFPA 2-2016 [Section No. 13.3.2.2.7]



Public Input No. 380-NFPA 2-2016 [Section No. 18.4.1]






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Public Input No. 165-NFPA 2-2016 [ New Section after 6.17.2.1.4.3 ]


6.17.2.1.4 Inlets to the Exhaust System.

The inlets to the exhaust systems shall be either designed to prevent blockage due to debris, foliage, ice, snow, etc. or the exhaust system shalldetect and react to the blockage.


For many products using ventilation, the effect is negated due to the blockage of the enclosure intakes with dead leaves, trash, snow and/or ice. This is a real hazard.

The proposed clause attempts to address this concern.




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6.17.2.1.4.3*

For [LH2 systems], exhaust shall be taken from a point within 12 in. (305 mm) of the floor. The use of supplemental inlets shall be allowed to be installed at

points above the 12 in. (305 mm) threshold level. [ 55: 6.16.4.2] ceiling. Inlets shall be provided within 12 in. (305 mm) of the floor.


For LH2 most releases will quickly vaporize and warm up making the requirement for a ceiling level exhaust and floor level inlet appropriate. The room air needs to be swept from bottom to top.




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Public Input No. 316-NFPA 2-2016 [ New Section after 6.17.2.1.5 ]

6.17.2.1.5 Recirculation of Exhaust

Exhaust ventilation shall not be recirculated. [ 55 :6.16.5]


This change adds this requirement from NFPA 55 into NFPA 2. Currently it is missing.




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Public Input No. 166-NFPA 2-2016 [ Section No. 6.17.2.1.5 ]


The location of both the exhaust and inlet air openings shall be designed to provide air movement across all portions of the floor or ceiling t ceiling of theroom or area to prevent the accumulation of [hydrogen] within the ventilated space. [ 55: 6.16.4.4]


Hydrogen is much lighter than air and will not accumulate along the floor. There is no need to ventilate the floor unless a heavier than air hazardous gas is present also, which is outside of the scope of this clause.




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The location of both the exhaust and inlet air openings shall be designed to provide air movement across all portions of the floor or [-] ceiling of the room orarea to prevent the accumulation of [hydrogen] within the ventilated space. [55:6.16.4.4]


Deletes text from 55 extract using bracketed format that required the floor to be swept. Since hydrogen is lighter than air this situation applies to the ceiling not the floor.




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6.17.2.1.5 Recirculation of Exhaust 4 .

The location of both the exhaust and inlet air openings shall be designed to provide air movement across all portions of the floor or ceiling of the room orarea to prevent the accumulation of [hydrogen] within the ventilated space. [55:6.16.4.4]


Currently this section is not a correct extract and does not address re circulation of exhaust but rather is another requirement for Inlets to the exhaust system. This change correctly aligns text with NFPA 55. The extract tag can remain.




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Ventilation discharge systems shall terminate at a point not less than 50 ft (15 m) from intakes of air-handling systems, air-conditioning equipment, and aircompressors. [ 55: 6.16.6] unless otherwise stated in a hardware specific, industry approved, installation standard (e.g. NFPA 37 & NFPA 853).


We are inconsistent with other lighter than air applications standards. We should refer to the other two product installation standards; NFPA 37 (Stationary IC Engines) and NFPA 853 (Stationary Fuel Cells).

NFPA 37 states:

4.1.2.2.1* Dedicated detached structures shall be of noncombustible or fire-resistive construction.

4.1.2.2.2 Dedicated detached structures shall be located at least 1.5 m (5 ft) from openings in walls and at least 1.5 m (5 ft) from structures having combustible walls. A minimum separation shall not be required where any of the following conditions exist:

(1) The exposing wall of the detached structure has a fire resistance rating of at least 1 hour.(2) The exposed wall of the adjacent structure has a fire resistance rating of at least 1 hour.(3) The detached structure is protected by an automatic fire protection system.

NFPA 853 states:

5.2.3 The exhaust outlet(s) from process areas or areas that contain fuel bearing components of a fuel cell power system shall be located at least 4.6 m (15 ft) from heating, ventilating, and air-conditioning (HVAC) air intakes, windows, doors, and other openings into buildings.

5.2.3.1 The exhaust outlet(s) shall not be directed onto walkways or other paths of travel for pedestrians.

5.2.3.2 The area classification around outlets from processes or compartments that contain fuel-bearing components shall be in accordance with Article 500 or Article 505 of NFPA 70, National Electrical Code.

Both aforementioned standards have been adopted by the ICC (IMC 915 and 924) for a number of years. NFPA 37 was first published in 1905. NFPA 853 was first published in 2000.




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(A) Ventilation discharge systems shall terminate at a point not less than 50 ft (15 m) from intakes of air-handling systems, air-conditioning equipment,and air compressors. [ 55: 6.16.6] air compressors , windows, doors, and other openings into buildings . []

(B) Hydrogen generation system ventilation outlets that exhaust flammable gas in concentration exceeding 25 percent of the lower LEL shall not bedirected onto walkways or other paths of travel for pedestrians.

(C) Reformer burner exhausts shall be located and installed in accordance with Chapter 12 of NFPA 54.



In following sections of NFPA 2 where ventilation is required, most point to Section 6.17, some repeat similar requirements, some set up potentially conflicting requirements and some add additional requirements specific to the type of installation requiring the exhaust ventilation.




Public Input No. 358-NFPA 2-2016 [Sections 6.17.1, 6.17.2] Part of package





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6.17.2.1.7 Air Intakes.

Storage and use of GH2 or LH2 not addressed by a hardware specific, industry approved, installation standard (e.g. NFPA 37 & NFPA 853) shall be

located not less than 50 ft (15 m) from air intakes.


See comments for 6.17.2.1.6.




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6.21 Cleaning and Purging of Piping Systems.

6.21.1 General.

6.21.1.1

[Hydrogen] systems shall be cleaned and purged in accordance with the requirements of Section 6.21 when one or more of the following conditions exist:

(1) The system is installed and prior to being placed into service.

(2) There is a change in service.

(3)

(4)

[55:7.1.18.1.1]

6.21.1.2

Cleaning and purging of the internal surfaces of [hydrogen] systems shall be conducted by qualified individuals trained in cleaning and purging operationsand procedures, including the recognition of potential hazards associated with cleaning and purging. [55:7.1.18.1.2]

6.21.1.3*

A written cleaning or purging procedure shall be provided to establish the requirements for the cleaning and purging operations to be conducted.[55:7.1.18.1.3]

6.21.1.3.1*

An independent or third-party review of the written procedure shall be conducted after the procedure has been written and shall accomplish the following:

(1) Evaluate hazards, errors, and malfunctions related to each step in the procedure

(2) Review the measures prescribed in the procedure for applicability

(3) Make recommendations for additional hazard mitigation measures if deemed to be necessary

[55:7.1.18.1.3.1]

6.21.1.3.2

The completed written procedure shall be:

(1) Maintained on site by the facility owner/operator

(2) Provided to operating personnel engaged in cleaning or purging operations

(3) Made available to the AHJ upon request

[55:7.1.18.1.3.2]

6.21.1.3.3

Where generic cleaning or purging procedures have been established, a job-specific operating procedure shall not be required. [55:7.1.18.1.3.3]

6.21.1.3.4

Generic procedures shall be reviewed when originally published or when the procedure or operation is changed. [55:7.1.18.1.3.4]

6.21.1.4

Written procedures to manage change to process materials, technology, equipment, procedures, and facilities shall be established and implemented.[654:4.3]

6.21.1.4.1

The management-of-change procedures shall ensure that the following topics are addressed prior to any change:

(1) The technical basis for the proposed change

(2) The safety and health implications

(3) Whether the change is permanent or temporary

(4) Modifications to the cleaning and purging procedures

(5) Employee training requirements

(6) Authorization requirements for the proposed change

[56:4.6.1]

6.21.1.4.2*

Implementation of the management-of-change procedures shall not be required for replacements-in-kind. [56:4.6.2]

6.21.1.4.3

The written cleaning and purging procedure, as required by 6.21.1.3, shall be updated to incorporate the change. [56:4.6.3]

6.21.1.5

Prior to cleaning or purging [in, hydrogen] piping systems shall be inspected and tested to determine that the installation, including the materials ofconstruction, and method of fabrication, comply with the requirements of the design standard used and the intended application for which the system wasdesigned. [55:7.1.18.1.5]

6.21.1.5.1

Inspection and testing of piping systems shall not be required to remove a system from service. [55:7.1.18.1.5.1]

* There are alterations or repair of the system, involving the replacement of parts or addition to the piping system and prior to returning the system toservice.

* The design standards or written procedures specify cleaning or purging.


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6.21.1.5.2*

Personnel in the affected area(s), as determined by the cleaning or purging procedure, shall be informed of the hazards associated with the operationalactivity and notified prior to the initiation of any such activity. [55:7.1.18.1.5.3]


Cleaning, purging, purge - cause confusion and may result in the reader assuming the mandated cleaning procedure is a gas blow. Not a good idea.

Thinking it over, we should not discuss purging or purges. The manufacturer is required here to generate a cleaning procedure. OSHA requires that the equipment have a lock out tag out (LOTO) to do that procedure. Inerting a fuel line is a LOTO for the cleaning spec. Handle it this way and we are clean and green.




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6.21.1 General.

The contamination of a system or of the hydrogen within a system may present safety issues with the system or with the use of the hydrogenexiting the system.

6.21.1.1

[Hydrogen] systems shall be cleaned and purged in accordance with the requirements of Section 6.21 when one or more of the following conditions exist:



(3)

(4)

[55:7.1.18.1.1]

6.21.1.2

Cleaning and purging of the internal surfaces of [hydrogen] systems shall be conducted by qualified individuals trained in cleaning and purging operationsand procedures, including the recognition of potential hazards associated with cleaning and purging. [55:7.1.18.1.2]

6.21.1.3*


6.21.1.3.1*





[55:7.1.18.1.3.1]

6.21.1.3.2





[55:7.1.18.1.3.2]

6.21.1.3.3

Where generic cleaning or purging procedures have been established, a job-specific operating procedure shall not be required. [55:7.1.18.1.3.3]

6.21.1.3.4

Generic procedures shall be reviewed when originally published or when the procedure or operation is changed. [55:7.1.18.1.3.4]

6.21.1.4

Written procedures to manage change to process materials, technology, equipment, procedures, and facilities shall be established and implemented.[654:4.3]

6.21.1.4.1








[56:4.6.1]

6.21.1.4.2*


6.21.1.4.3

The written cleaning and purging procedure, as required by 6.21.1.3, shall be updated to incorporate the change. [56:4.6.3]

6.21.1.5

Prior to cleaning or purging [in, hydrogen] piping systems shall be inspected and tested to determine that the installation, including the materials ofconstruction, and method of fabrication, comply with the requirements of the design standard used and the intended application for which the system wasdesigned. [55:7.1.18.1.5]

6.21.1.5.1

Inspection and testing of piping systems shall not be required to remove a system from service. [55:7.1.18.1.5.1]


* The design standards or written procedures specify cleaning or purging.


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6.21.1.5.2*

Personnel in the affected area(s), as determined by the cleaning or purging procedure, shall be informed of the hazards associated with the operationalactivity and notified prior to the initiation of any such activity. [55:7.1.18.1.5.3]


There needs to be some explanation as to why this section exists.




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6.21.1.1

[Hydrogen] systems shall be demonstrated and documented as cleaned and purged in accordance with the requirements of Section 6.21 when one ormore of the following conditions exist:



(3)

(4)

[ 55: 7.1.18.1.1]A.6.21.1.1(3) The replacement of parts in a system to repair leaks, the addition of gaskets, and similar routine maintenance is not intended toestablish the need for cleaning of the entire piping system. The requirement is to not introduce new contaminants during the repair (e.g. cuttingoils, grinding debris, contaminated hardware).

Conversely, when a piping system is extended, or when the system needs to be rendered safe for maintenance purposes, a purge of the system [out ofservice] before disassembly will likely be required as will internal cleaning if new piping or materials of construction are introduced

A.6.21.1.1(4) Cleaning and a purge of [hydrogen] systems (see 3.3.196) can be conducted as individual functions, i.e., just cleaning or just purging, or incombination as required to satisfy the requirements of the procedures.


There are several issues. First the AHJ does not clean or purge systems. Usually, they are not present when it happens. The best the AHJ can enforce is that it has been demonstrated and documented

The second is that this clause should refer to the definition in 3.3.196 and not 3.3.197. The former involves an inerting step. The latter is a “gas blow”, which is a dangerous process that NFPA and the US Chemical Safety Board has been reticent to suggest after the KLEEN ENERGY incident of 2010 which killed five and injured more than fifty.

For A6.21.1.1.2(3)

Several points to address. First this clause needs some clarification on the first requirement, cleanliness. Lack of cleanliness with high pressure small bore hardware can in of itself be a safety hazard; controls binding.

The second point is that there are two requirements here. One stipulated, one embedded. The embedded one will be missed. The requirement merits a separate paragraph so that it is obvious that there are two requirements.

The third point is that this clause should refer to the definition in 3.3.196 and not 3.3.197. See comment for 6.21.1.1(4).

A.6.21.1.1(4) There is a major difference between an inerting process and a risky cleaning process. Terms should be selected to avoid confusing the two. This should refer to the definition in 3.3.196 and not 3.3.197.

3.3.196* Purge [Special Atmosphere Applications]. The replacement of a flammable, indeterminate, or high oxygen bearing atmosphere with another gas that, when complete, results in a nonflammable final state. [86, 2015]

Terms should be carefully selected to avoid confusing the two.

3.3.197 Purging Gas Blow. A method used to free the internal volume of a piping system of unwanted contents that results in the existing contents being removed or replaced. [55, 2016]




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6.21.1.2

Cleaning and purging of of the internal surfaces of [hydrogen] systems shall be conducted by qualified individuals trained in cleaning and purgingoperations and procedures, including the recognition of potential hazards associated with cleaning and purging. [55:7.1.18.1.2]


As written, this can be interpreted as mandating a gas blow. See comment for 6.21.1.1(4). We should not be mandating a gas blow




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6.21.1.3*


6.21.1.3.1*





[ 55: 7.1.18.1.3.1]

6.21.1.3.2





[ 55: 7.1.18.1.3.2]

6.21.1.3.3

Where generic cleaning or purging procedures have been established, a job-specific operating procedure shall not be required. [ 55: 7.1.18.1.3.3]

6.21.1.3.4

Generic procedures shall be reviewed when originally published or when the procedure or operation is changed. [ 55: 7.1.18.1.3.4]


6.21.1.3 As written, this can be interpreted as mandating a gas blow. See comment for 6.21.1.1(4). We should not be mandating a gas blow. Cover inerting of the line in the LOTO requirements to be included in the manuals.

6.21.1.3.1 Delete. Not enforceable

6.21.1.3.2 Merge 2nd paragraph of 6.21.1.3

6.21.1.3.3 Delete. Redundant.

6.21.1.3.4 Delete. Redundant. Who is authorized and/or to review these procedures? The AHJ? An AHJ appointed third party? Don’t go here




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6.21.1.4

Written procedures to manage change to process materials, technology, equipment, procedures, and facilities shall be established and implemented .[ 654: 4.3] by the owner/operator

6.21.1.4.1








[56:4.6.1]

6.21.1.4.2*


6.21.1.4.3

The written cleaning and purging procedure, as required by 6.21.1.3, shall be updated to incorporate the change. [ 56: 4.6.3] before implementation ofthe change. Changes shall be made available upon request to the AHJ.


6.21.1.4 Who is required to do this? The AHJ? The manufacturer who may go out of business? No the owner/operator who is liable in an incident

6.21.1.4.3 If the paperwork is allow to lag, it won’t be done. Require the paperwork be present for conducting the “change”.




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6.21.1.5

Prior to cleaning or purging [in , a hydrogen ] piping systems shall be inspected and tested by the owner/operator to determine that the installation,including the materials of construction, and method of fabrication, comply with the requirements of the design standard used and the intended applicationfor which the system was designed. [ 55: 7.1.18.1.5]

6.21.1.5.1

Inspection and testing of piping systems shall not be required to remove a system from service. [ 55: 7.1.18.1.5.1]

6.21.1.5. 2*

Personnel in the affected area(s), as determined by the cleaning or purging procedure, shall be informed by the owner/operator of the hazards associatedwith the operational activity and notified prior to the initiation of any such activity. [ 55: 7.1.18.1.5.3] The owner/operator shall maintain records of thenotification/training and the records shall be made available to the AHJ upon request.


6.21.1.5 See comment for 6.21.1.1(4).6.21.1.5.1 Delete. What has this to do with cleaning? Why would we expect to be required to inspect anything being removed from service? The expectation would be to inspect before returning to service?6.21.1.5.2 Amend. Who is responsible to notify? Otherwise not actionable.




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Chapter 7 Gaseous Hydrogen

7.1 General.

7.1.1

The storage, use, and handling of GH2 shall comply with this chapter in addition to other applicable requirements of this code.

7.1.1.1

Where specific requirements are provided in other chapters, those specific requirements shall apply.

7.1.1.2

Where there is a conflict between a general requirement and a specific requirement, the specific requirement shall be applicable.

7.1.1.3

The occupancy of a building or structure, or portion thereof, where hydrogen is stored or used shall be classified in accordance with the adopted buildingcode.

7.1.2* GH2 Systems.

7.1.2.1 [System] Design.

[GH2] systems shall be designed for the intended use and shall be designed by persons competent in such design. [55:7.1.2.2]

7.1.2.2 Installation.

Installation of bulk [GH2] systems shall be supervised by personnel knowledgeable in the application of the standards for their construction and use.

[55:7.1.2.2]

7.1.2.3 Controls.

7.1.2.3.1

[GH2] system controls shall be designed to prevent materials from entering or leaving the process at an unintended time, rate, or path. [55:7.3.1.2.1]

7.1.2.3.2

Automatic controls shall be designed to be fail-safe. [55:7.3.1.2.2]

7.1.3 Listed or Approved Hydrogen Equipment.

Listed or approved hydrogen-generating and hydrogen-consuming equipment shall be in accordance with the listing requirements and manufacturers’instructions. [55:10.2.8.1]

7.1.4* Metal Hydride Storage Systems.

7.1.4.1 General.

7.1.4.1.1

The storage and use of metal hydride storage systems shall be in accordance with 7.1.4. [55:10.2.9.1.1]

7.1.4.1.2 Metal Hydride Systems Storing or Supplying GH2.

Those portions of the system that are used as a means to store or supply [GH2] shall also comply with Sections 7.2 or 7.3 as applicable. [55:10.2.9.1.2]

7.1.4.1.3 Classification.

The hazard classification of the metal hydride storage system shall be based on the [GH2] stored without regard to the metal hydride content.

[55:10.2.9.1.3]

7.1.4.1.4* Listed or Approved Systems.

Metal hydride storage systems shall be listed or approved for the application and designed in a manner that prevents the addition or removal of the metalhydride by other than the original equipment manufacturer. [55:10.2.9.1.4]

7.1.4.1.5 Design and Construction of Containers.

[GH2] cylinders, containers, and tanks used for metal hydride storage systems shall be designed and constructed in accordance with 7.1.5.1.

[55:10.2.9.1.5]

7.1.4.1.6 Service Life and Inspection of Containers.

Metal hydride storage system cylinders, containers, and tanks shall be inspected, tested, and requalified for service at not less than 5-year intervals.[55:10.2.9.1.6]

7.1.4.1.7 Marking and Labeling.

Marking and labeling of cylinders, containers, tanks, and systems shall be in accordance with 7.1.5 and the requirements in 7.1.4.1.7.1 through7.1.4.1.7.4. [55:10.2.9.1.7]

7.1.4.1.7.1 System Marking.

Metal hydride storage systems shall be marked with the following:

(1) Manufacturer’s name

(2) Service life indicating the last date the system can be used

(3) A unique code or serial number specific to the unit

(4) System name or product code that identifies the system by the type of chemistry used in the system

(5) Emergency contact name, telephone number, or other contact information

(6) Limitations on refilling of containers to include rated charging pressure and capacity

[55:10.2.9.1.7.1]


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7.1.4.1.7.2 Valve Marking.

Metal hydride storage system valves shall be marked with the following:


(2) Service life indicating the last date the valve can be used

(3) Metal hydride service in which the valve can be used or a product code that is traceable to this information

[55:10.2.9.1.7.2]

7.1.4.1.7.3 Pressure Relief Device Marking.

Metal hydride storage system pressure relief devices shall be marked with the following:


(2) Metal hydride service in which the device can be used or a product code that is traceable to this information

(3) Activation parameters to include temperature, pressure, or both

[55:10.2.9.1.7.3]

(A)

The required markings for pressure relief devices that are integral components of valves used on cylinders, containers, and tanks shall be allowed to beplaced on the valve. [55:10.2.9.1.7.3(A)]

7.1.4.1.7.4 Pressure Vessel Markings.

Cylinders, containers, and tanks used in metal hydride storage systems shall be marked with the following:


(2) Design specification to which the vessel was manufactured

(3) Authorized body approving the design and initial inspection and test of the vessel

(4) Manufacturer’s original test date

(5) Unique serial number for the vessel

(6) Service life identifying the last date the vessel can be used


[55:10.2.9.1.7.4]

7.1.4.1.8 Temperature Extremes.

Metal hydride storage systems, whether full or partially full, shall not be exposed to artificially created high temperatures exceeding 125°F (52°C) orsubambient (low) temperatures unless designed for use under the exposed conditions. [55:10.2.9.1.8]

7.1.4.1.9 Falling Objects.

Metal hydride storage systems shall not be placed in areas where they are capable of being damaged by falling objects. [55:10.2.9.1.9]

7.1.4.1.10 Refilling of Containers.

The refilling of listed or approved metal hydride storage systems shall be in accordance with the listing requirements and manufacturers’ instructions.[55:10.2.9.1.11]

7.1.4.1.10.1 Industrial Trucks.

The refilling of metal hydride storage systems serving powered industrial trucks shall be in accordance with the requirements of Chapter 10.

7.1.4.1.10.2 Hydrogen Purity.

The purity of [GH2] used for the purpose of refilling containers shall be in accordance with the listing and the manufacturers’ instructions. [55:10.2.9.1.11.2]

7.1.4.1.11 Electrical.

Electrical components for metal hydride storage systems shall be designed, constructed, and installed in accordance with NFPA 70. [55:10.2.9.1.12]

7.1.4.2 Portable Containers or Systems.

7.1.4.2.1 Securing Containers.

Cylinders, containers, and tanks shall be secured in accordance with 7.1.7.4. [55:10.2.9.2.1]

7.1.4.2.1.1 Use on Mobile Equipment.

Where a metal hydride storage system is used on mobile equipment, the equipment shall be designed to restrain cylinders, containers, or tanks fromdislodgement, slipping, or rotating when the equipment is in motion. [55:10.2.9.2.1.1]

7.1.4.2.1.2 Motorized Equipment.

(A)

Metal hydride storage systems used on motorized equipment shall be installed in a manner that protects valves, pressure regulators, fittings, and controlsagainst accidental impact. [55:10.2.9.2.1.2]

(B)

Metal hydride storage systems, including cylinders, containers, tanks, and fittings, shall not extend beyond the platform of the mobile equipment.[55:10.2.9.2.1.2(A)]

7.1.4.2.2 Valves.

Valves on cylinders, containers, and tanks shall remain closed except when containers are connected to closed systems and ready for use. [55:10.2.9.2.2]

7.1.5 Cylinders, Containers, and Tanks.


Cylinders, containers, and tanks shall be designed, fabricated, tested, and marked (stamped) in accordance with regulations of DOT, Transport Canada(TC) Transportation of Dangerous Goods Regulations, or the ASME Boiler and Pressure Vessel Code, “Rules for the Construction of Unfired PressureVessels,” Section VIII. [55:7.1.5.1]

7.1.5.2 Defective Cylinders, Containers, and Tanks.


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7.1.5.2.1

Defective cylinders, containers, and tanks shall be returned to the supplier. [55:7.1.5.2.1]

7.1.5.2.2

Suppliers shall repair the cylinders, containers, and tanks, remove them from service, or dispose of them in an approved manner. [55:7.1.5.2.2]

7.1.5.3 Supports.

Stationary cylinders, containers, and tanks shall be provided with engineered supports of noncombustible material on noncombustible foundations.[55:7.1.5.3]

7.1.5.4 Cylinders, Containers, and Tanks Containing Residual Gas.

[GH2] cylinders, containers, and tanks containing residual product shall be treated as full except when being examined, serviced, or refilled by a gas

manufacturer, authorized cylinder requalifier, or distributor. [55:7.1.5.4]

7.1.5.5 Pressure Relief Devices.

7.1.5.5.1

When required by 7.1.5.5.2, pressure relief devices shall be provided to protect containers and systems containing [GH2] from rupture in the event of

overpressure from thermal exposure. [55:7.1.5.5.1]

7.1.5.5.2

Pressure relief devices to protect containers shall be designed and provided in accordance with CGA S-1.1, Pressure Relief Device Standards— Part 1 —Cylinders for Compressed Gases, for cylinders; CGA S-1.2, Pressure Relief Device Standards— Part 2 — Cargo and Portable Tanks for CompressedGases, for portable tanks; and CGA S-1.3, Pressure Relief Device Standards — Part 3 — Stationary Storage Containers for Compressed Gases, forstationary tanks or in accordance with applicable equivalent requirements in the country of use. [55:7.1.5.5.2]

7.1.5.5.3

Pressure relief devices shall be sized in accordance with the specifications to which the container was fabricated. [55:7.1.5.5.3]

7.1.5.5.4

The pressure relief device shall have the capacity to prevent the maximum design pressure of the container or system from being exceeded. [55:7.1.5.5.4]

7.1.5.5.5

Pressure relief devices shall be arranged to discharge unobstructed to the open air in such a manner as to prevent any impingement of escaping gas uponthe container, adjacent structures, or personnel. This requirement shall not apply to DOT specification containers having an internal volume of 2.0 scf

(0.057 Nm3) or less. [55:7.1.5.5.5]

7.1.5.5.6

Pressure relief devices or vent piping shall be designed or located so that moisture cannot collect and freeze in a manner that would interfere withoperation of the device. [55:7.1.5.5.6]

7.1.6 Labeling Requirements.

7.1.6.1 Containers.

Individual [GH2] cylinders, containers, and tanks shall be marked or labeled in accordance with DOT requirements or those of the applicable regulatory

agency. [55:7.1.7.1]

7.1.6.2 Label Maintenance.

The labels applied by the gas manufacturer to identify the liquefied or nonliquified [GH2] cylinder contents shall not be altered or removed by the user.

[55:7.1.7.2]

7.1.6.3 Stationary GH2 Cylinders, Containers, and Tanks.

7.1.6.3.1

Stationary [GH2] cylinders, containers, and tanks shall be marked in accordance with NFPA 704. [55:7.1.7.3.1]

7.1.6.3.2

Markings shall be visible from any direction of approach. [55:7.1.7.3.2]

7.1.6.4 Piping Systems.

7.1.6.4.1

Except as provided in 7.1.6.4.2, piping systems shall be marked in accordance with ASME A13.1, Scheme for the Identification of Piping Systems, orother applicable approved [codes and] standards as follows:

(1) Marking shall include the name of the gas and a direction-of-flow arrow.

(2) Piping that is used to convey more than one gas at various times shall be marked to provide clear identification and warning of the hazard.

(3) Markings for piping systems shall be provided at the following locations:

(a) At each critical process control valve

(b) At wall, floor, or ceiling penetrations

(c) At each change of direction

(d) At a minimum of every 20 ft (6.1 m) or fraction thereof throughout the piping run

[55:7.1.7.4.1]

7.1.6.4.2

Piping within gas manufacturing plants, gas processing plants, refineries, and similar occupancies shall be marked in an approved manner. [55:7.1.7.4.2]

7.1.6.5 Marking.

7.1.6.5.1

Hazard identification signs shall be provided in accordance with 4.13.2. [55:10.2.1.1]


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7.1.6.5.2

In addition, the area in which a hydrogen system is located shall be permanently placarded as follows:

WARNING: HYDROGEN — FLAMMABLE GAS — NO SMOKING — NO OPEN FLAMES

[55:10.2.1.2]

7.1.7 Security.

7.1.7.1 General.

[GH2] cylinders, containers, tanks, and systems shall be secured against accidental dislodgement and against access by unauthorized personnel.

[55:7.1.8.1]

7.1.7.2* Security of Areas.

Storage, use, and handling areas shall be secured against unauthorized entry. [55:7.1.8.2]

7.1.7.2.1

Administrative controls shall be allowed to be used to control access to individual storage, use, and handling areas located in secure facilities notaccessible by the general public. [55:7.1.8.2.1]

7.1.7.3 Physical Protection.

7.1.7.3.1

[GH2] cylinders, containers, tanks, and systems that could be exposed to physical damage shall be protected. [55:7.1.8.3.1]

7.1.7.3.2

Guard posts or other means shall be provided to protect [GH2] cylinders, containers, tanks, and systems indoors and outdoors from vehicular damage in

accordance with. Section 4.14. [55:7.1.8.3.2]

7.1.7.3.3

Where guard posts are installed, they shall be in accordance with 4.14.1.2.

7.1.7.4 Securing GH2 Cylinders, Containers, and Tanks.

[GH2] cylinders, containers, and tanks in use or in storage shall be secured to prevent them from falling or being knocked over by corralling them and

securing them to a cart, framework, or fixed object by use of a restraint, unless otherwise permitted by 7.1.7.4.1 and 7.1.7.4.2. [55:7.1.8.4]

7.1.7.4.1

[GH2] cylinders, containers, and tanks in the process of examination, servicing, and refilling shall not be required to be secured. [55:7.1.8.4.1]

7.1.7.4.2

At cylinder-filling plants, authorized cylinder requalifier’s facilities, and distributors’ warehouses, the nesting of cylinders shall be permitted as a means tosecure cylinders. [55:7.1.8.4.2]

7.1.8 Valve Protection.

7.1.8.1* General.

[GH2] cylinder, container, and tank valves shall be protected from physical damage by means of protective caps, collars, or similar devices. [55:7.1.9.1]

7.1.8.1.1

Valve protection of individual valves shall not be required to be installed on individual cylinders, containers, or tanks installed on tube trailers or similartransportable bulk gas systems equipped with manifolds that are provided with a means of physical protection that will protect the valves from physicaldamage when the equipment is in use. Protective systems required by DOT for over the road transport shall provide an acceptable means of protection.[55:7.1.9.1.1]

7.1.8.1.1.1

Valve protection of individual valves shall not be required to be installed on individual cylinders, containers, or tanks that comprise bulk or non-bulk gassystems where the containers are stationary, or portable equipped with manifolds that are provided with physical protection in accordance with 4.1.4 and7.1.7.3 or other approved means. Protective systems required by DOT for over the road transport shall provide an acceptable means of protection.[55:7.1.9.1.1.1]

7.1.8.2 Valve-Protective Caps.

Where [GH2] cylinders, containers, and tanks are designed to accept valve-protective caps, the user shall keep such caps on the [GH2] cylinders,

containers, and tanks at all times, except when empty, being processed, or connected for use. [55:7.1.9.2]

7.1.9 Separation from Hazardous Conditions.

7.1.9.1 General.

[GH2] cylinders, containers, tanks, and systems in storage or use shall be separated from materials and conditions that present exposure hazards to or

from each other. [55:7.1.10.1]

7.1.9.1.1* Clearance from Combustibles and Vegetation.

Combustible waste, vegetation, and similar materials shall be kept a minimum of 10 ft (3.1 m) from [GH2] cylinders, containers, tanks, and systems.

[55:7.1.10.3]

7.1.9.1.1.1

A noncombustible partition without openings or penetrations and extending not less than 18 in. (457 mm) above and to the sides of the storage area shallbe permitted in lieu of the minimum distance. [55:7.1.10.3.1]

7.1.9.1.1.2

The noncombustible partition shall either be an independent structure or the exterior wall of the building adjacent to the storage area. [55:7.1.10.3.2]

7.1.9.1.2 Ledges, Platforms, and Elevators.

[GH2] cylinders, containers, and tanks shall not be placed near elevators, unprotected platform ledges, or other areas where [GH2] cylinders, containers,

or tanks could fall distances exceeding one-half the height of the cylinder, container, or tank. [55:7.1.10.4]



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[GH2] cylinders, containers, and tanks, whether full or partially full, shall not be exposed to temperatures exceeding 125°F (52°C) or subambient (low)

temperatures unless designed for use under such exposure. [55:7.1.10.5]

7.1.9.1.3.1

[GH2] cylinders, containers, and tanks that have not been designed for use under elevated temperature conditions shall not be exposed to direct sunlight

outdoors where ambient temperatures exceed 125°F (52°C). The use of a weather protected structure or shaded environment for storage or use shall bepermitted as a means to protect against direct exposure to sunlight. [55:7.1.10.5.1]


[GH2] cylinders, containers, and tanks shall not be placed in areas where they are capable of being damaged by falling objects. [55:7.1.10.6]

7.1.9.1.5 Heating.

[GH2] cylinders, containers, and tanks, whether full or partially full, shall not be heated by devices that could raise the surface temperature of the cylinder,

container, or tank to above 125°F (52°C). [55:7.1.10.7]

7.1.9.1.5.1 Electrically Powered Heating Devices.

Electrical heating devices shall be in accordance with NFPA 70. [55:7.1.10.7.1]

7.1.9.1.5.2 Fail-Safe Design.

Devices designed to maintain individual [GH2] cylinders, containers, or tanks at constant temperature shall be designed to be fail-safe. [55:7.1.10.7.2]

7.1.9.1.6 Sources of Ignition.

Open flames and high-temperature devices shall not be used in a manner that creates a hazardous condition. [55:7.1.10.8]

7.1.9.1.7 Exposure to Chemicals.

[GH2] cylinders, containers, and tanks shall not be exposed to corrosive chemicals or fumes that could damage cylinders, containers, tanks, or valve-

protective caps. [55:7.1.10.9]

7.1.9.1.8 Exposure to Electrical Circuits.

[GH2] containers, cylinders, and tanks shall not be placed where they could become a part of an electrical circuit. [55:7.1.10.10]

7.1.9.1.8.1*

Electrical devices mounted on [GH2] piping, cylinders, containers, or tanks shall be installed, grounded, and bonded in accordance with the methods

specified in NFPA 70(NEC). [55:7.1.10.10.1]

7.1.10 Service and Repair.

Service, repair, modification, or removal of valves, pressure relief devices, or other [GH2] cylinder, container, or tank appurtenances shall be performed by

trained personnel and with the permission of the container owner. [55:7.1.11]

7.1.11 Unauthorized Use.

[GH2] cylinders, containers, and tanks shall not be used for any purpose other than to serve as a vessel for containing the product for which it was

designed. [55:7.1.12]

7.1.12 Cylinders, Containers, and Tanks Exposed to Fire.

[GH2] cylinders, containers, and tanks exposed to fire shall not be used or shipped while full or partially full until they are requalified in accordance with the

pressure vessel code under which they were manufactured. [55:7.1.13]

7.1.13 Leaks, Damage, or Corrosion.

7.1.13.1* Removal From Service.

Leaking, damaged, or corroded [GH2] cylinders, containers, and tanks shall be removed from service. [55:7.1.14.1]

7.1.13.2 Replacement and Repair.

Leaking, damaged, or corroded [GH2] systems shall be replaced or repaired. [55:7.1.14.2]

7.1.13.3* Handling of Cylinders, Containers, and Tanks Removed from Service.

[GH2] cylinders, containers, and tanks that have been removed from service shall be handled in an approved manner. [55:7.1.14.3]

7.1.14 Surfaces.

7.1.14.1

To prevent bottom corrosion, cylinders, containers, and tanks shall be protected from direct contact with soil or surfaces where water might accumulate.[55:7.1.15.1]

7.1.14.2

Surfaces shall be graded to prevent accumulation of water. [55:7.1.15.2]

7.1.15 Piping.

7.1.15.1* Piping Systems.

Piping, tubing, fittings, and related components shall be designed, fabricated, and installed in accordance with applicable parts of ASME B31.3, Code forProcess Piping, and Sections 704.1.2.3, 704.1.2.4, and 704.1.2.5 of the ICC International Fuel Gas Code (IFGC). Cast-iron pipe, valves, and fittings shallnot be used.

7.1.15.1.1

Prior to acceptance and initial operation, all piping installations shall be inspected and pressure tested in accordance with ASME B31.12, Hydrogen Pipingand Pipelines, and ICC International Fuel Gas Code (IFGC), Section 705. [55:10.2.2.1]

7.1.15.1.2

In addition to the requirements of 7.1.15.1, brazing materials used for joints in piping and tubing systems shall have a melting point about 1000°F (538°C).[55:10.2.2.2]

7.1.15.1.3

Underground piping system shall be in accordance with 7.1.15.3. [55:10.2.2.3]


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7.1.15.1.4 Integrity.

Piping, tubing, pressure regulators, valves, and other apparatus shall be kept gastight to prevent leakage. [55:7.3.1.3.1]

7.1.15.1.5 Backflow Prevention.

Backflow prevention or check valves shall be provided where the backflow of hazardous materials could create a hazardous condition or cause theunauthorized discharge of hazardous materials. [55:7.3.1.3.2]

7.1.15.2 Equipment Assembly.

7.1.15.2.1

Valves, gauges, regulators, and other accessories used for hydrogen compressed gas systems shall be specified for hydrogen service by the manufactureror the hydrogen supplier. [55:10.2.4.1]

7.1.15.2.2

Storage containers, piping, valves, regulating equipment, and appurtenances serving hydrogen compressed gas systems shall be protected againstphysical damage and tampering. [55:10.2.4.1.1]

7.1.15.2.3

Cabinets or enclosures containing hydrogen control or operating equipment shall be ventilated to prevent the accumulation of hydrogen. [55:10.2.4.2]

7.1.15.2.4

Mobile hydrogen supply units used as part of a hydrogen compressed gas system shall be secured to prevent movement. [55:10.2.4.3]

7.1.15.2.5

Mobile hydrogen supply units shall be electrically bonded to the storage system before hydrogen is discharged from the supply unit. [55:10.3.2.1]

7.1.15.3 Underground Piping.

7.1.15.3.1

Underground piping shall be of welded construction without valves, unwelded mechanical joints, or connections installed underground. [55:7.1.17.1]

7.1.15.3.1.1

Valves or connections located in boxes or enclosures shall be permitted to be installed underground where such boxes or enclosures are accessible fromabove ground and where the valves or connections contained are isolated from direct contact with earth or fill. [55:7.1.17.1.1]

7.1.15.3.1.2

Valve boxes or enclosures installed in areas subject to vehicular traffic shall be constructed to resist uniformly distributed and concentrated live loads inaccordance with the [adopted] building code for areas designated as vehicular driveways and yards, subject to trucking. [55:7.1.17.1.1.1]

7.1.15.3.1.3*

Piping installed in trench systems located below grade where the trench is open to above shall not be considered to be underground. [55:7.1.17.1.2]

7.1.15.3.2 Contact with Earth.

7.1.15.3.2.1

Gas piping in contact with earth or other material that could corrode the piping shall be protected against corrosion in an approved manner. [55:7.1.17.2]

7.1.15.3.2.2

When cathodic protection is provided, it shall be in accordance with 7.1.18. [55:7.1.17.2.1]

7.1.15.3.3

Underground piping shall be installed on at least 6 in. (150 mm) of well-compacted bedding material. [30:27.6.5.1]

7.1.15.3.4

In areas subject to vehicle traffic, the pipe trench shall be deep enough to permit a cover of at least 18 in. (450 mm) of well-compacted backfill material andpavement. [30:27.6.5.2]

7.1.15.3.5

In paved areas where a minimum 2 in. (50 mm) of asphalt is used, backfill between the pipe and the asphalt shall be permitted to be reduced to 8 in.(200 mm) minimum. [30:27.6.5.3]

7.1.15.3.6

In paved areas where a minimum 4 in. (100 mm) of reinforced concrete is used, backfill between the pipe and the concrete shall be permitted to bereduced to 4 in. (100 mm) minimum. [30:27.6.5.4]

7.1.15.3.7

In areas not subject to vehicle traffic, the pipe trench shall be deep enough to permit a cover of at least 12 in. (300 mm) of well-compacted backfill material.[55:7.1.17.7]

7.1.15.3.8

A greater burial depth shall be provided when required by the manufacturer’s instructions or where frost conditions are present. [30:27.6.5.6]

7.1.15.3.9

Piping within the same trench shall be separated horizontally by at least two pipe diameters. Separation need not exceed 9 in. (230 mm). [30:27.6.5.7]

7.1.15.3.10

Two or more levels of piping within the same trench shall be separated vertically by a minimum 6 in. (150 mm) of well-compacted bedding material.[30:27.6.5.8]

7.1.15.3.11

“As-built” drawings of the underground piping installation shall be maintained by the owner and shall be available upon request by the AHJ.

7.1.16 Valves.

7.1.16.1

Valves utilized on [GH2] systems shall be designed for the gas or gases and pressure intended and shall be accessible. [55:7.3.1.4.1]


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7.1.16.2

Valve handles or operators for required shutoff valves shall not be removed or otherwise altered to prevent access. [55:7.3.1.4.2]

7.1.17 GH2 Venting Systems.

Hydrogen-venting systems serving pressure relief devices discharging [GH2] to the atmosphere shall be in accordance with CGA G-5.5, Hydrogen Vent

Systems. [55:10.2.3]

7.1.17.1

Venting from the relief vents from the hydrogen supply piping serving listed fuel cell power systems shall be permitted to be discharged into an enclosureintegral to the fuel cell system where the concentration of hydrogen is diluted below 25 percent of the lower flammable limit (LFL) at the outlet of theenclosure. [55:10.2.3.1]

7.1.17.2

The hydrogen supply piping system shall be designed to isolate the source of hydrogen from the relief vent in the event of loss of dilution ventilation orpower. [55:10.2.3.1.1]


7.1.17.3.1

Venting of [GH2] shall be directed to an approved location. [55:7.3.1.5.1]

7.1.17.3.2

The termination point for piped vent systems serving cylinders, containers, tanks, and gas systems used for the purpose of operational or emergencyventing shall be in accordance with Section 6.16. [55:7.3.1.5.2]

7.1.18 Cathodic Protection.

Where required, cathodic protection shall be in accordance with 7.1.18. [55:7.1.6]

7.1.18.1 Operation.

Where installed, cathodic protection systems shall be operated and maintained to continuously provide corrosion protection. [55:7.1.6.1]

7.1.18.2 Inspection.

Container systems equipped with cathodic protection shall be inspected for [proper] operation by a cathodic protection tester. The frequency of inspectionshall be determined by the designer of the cathodic protection system. [55:7.1.6.2]

7.1.18.2.1

The cathodic protection tester shall be certified as being qualified by the National Association of Corrosion Engineers, International (NACE). [55:7.1.6.2.1]

7.1.18.3 Impressed Current Systems.

Systems equipped with impressed current cathodic protection systems shall be inspected in accordance with the requirements of the design and 7.1.18.2.[55:7.1.6.3]

7.1.18.3.1

The design limits of the cathodic protection system shall be available to the AHJ upon request. [55:7.1.6.3.1]

7.1.18.3.2

The system owner shall maintain the following records to demonstrate that the cathodic protection is in conformance with the requirements of the design:

(1) The results of inspections of the system

(2) The results of testing that has been completed

[55:7.1.6.3.2]

7.1.18.4 Corrosion Expert.

Repairs, maintenance, or replacement of a cathodic protection system shall be under the supervision of a corrosion expert certified by NACE. [55:7.1.6.4]

7.1.18.4.1

The corrosion expert shall be certified by NACE as a senior corrosion technologist, a cathodic protection specialist, or a corrosion specialist or shall be aregistered engineer with registration in a field that includes education and experience in corrosion control. [55:7.1.6.4.1]

7.1.19 Transfer.

Transfer of [GH2] between cylinders, containers, and tanks shall be performed by qualified personnel using equipment and operating procedures in

accordance with CGA P-1, Safe Handling of Compressed Gases in Containers. [55:7.3.1.9]

7.1.20 Compression and Processing Equipment.

Compression and gas processing equipment integral to hydrogen compressed gas storage systems shall be designed for use with GH2 and for maximum

pressures and temperatures to which it can be subjected under normal operating conditions. [55:10.2.5]

7.1.20.1

Compression and gas processing equipment shall have pressure relief devices that limit each stage pressure to the maximum allowable working pressurefor the compression cylinder and piping associated with that stage of compression. [55:10.2.5.1]

7.1.20.2

Where GH2 compression equipment is operated unattended, it shall be equipped with a high discharge and a low suction pressure automatic shutdown

control. [55:10.2.5.2]

7.1.20.3

Control circuits that automatically shut down shall remain down until manually activated or reset after a safe shutdown is performed. [55:10.2.5.3]

7.1.21 Stationary Compressors.

7.1.21.1 Valves.

(A)

Valves shall be installed such that each compressor is able to be isolated for maintenance. [55:10.2.5.4.1.1]


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(B)

The discharge line shall be equipped with a check valve to prevent the backflow of gas from high-pressure sources located downstream of the compressor.[55:10.2.5.4.1.2]

7.1.21.2 Foundations.

(A)

Foundations used for supporting equipment shall be designed and constructed to prevent frost heaving. [55:10.2.5.5.1]

(B)

The structural aspects of such foundations shall be designed and constructed in accordance with the provisions of the [adopted] building code.[55:10.2.5.5.2]

7.1.21.3 Emergency Shutdown.

When an emergency shutdown system is required, activation of the emergency shutdown system shall shut down operation of all compressors serving asingle gas installation. [55:10.2.5.6]

7.1.21.4 Relief Valves.

(A)

Each compressor shall be provided with a vent or relief device that will prevent overpressurizing of the compressor under normal or upset conditions.[55:10.2.5.7.1]

(B)

Pressure relief devices used to serve pumps or compression equipment shall be connected to a vent pipe system in accordance with 7.1.17.[55:10.2.5.7.2]

7.1.21.5 Pressure Monitoring.

The pressure on the compressor discharge shall be monitored by a control system. [55:10.2.5.8]

(A)

Discharge pressures in excess of the equipment design pressures shall cause the compressor to shut down. [55:10.2.5.8.1]

7.1.21.6 Protection.

Transfer piping and compressors shall be protected from vehicular damage. [55:10.2.5.9]

7.1.22 Use of GH2 for Inflation.

Inflatable equipment, devices, or balloons shall not be pressurized or filled with GH2.

7.1.23 Hydrogen Equipment Enclosures.

7.1.23.1

Hydrogen equipment enclosures (HEE) shall be in accordance with 7.1.23 when the total quantity of hydrogen stored in the enclosure or piped into the

enclosure exceeds 1000 scf (28.3 Nm3) or the enclosure contains hydrogen processing or generating equipment.

7.1.23.1.1

Subsection 7.1.23 does not apply to:

(1) Gas cabinets in accordance with Section 6.18

(2) Exhausted enclosures in accordance with 6.19

(3) Enclosures integral to fuel cell systems that are listed or approved in accordance with Chapter 12

(4) Enclosures integral to hydrogen generators that are listed or approved in accordance with Chapter 13

7.1.23.1.2

HEE shall be constructed of noncombustible materials.

7.1.23.2 Bonding and Grounding.

7.1.23.2.1

HEE grounding and equipment bonding within the enclosure shall comply with all of the following:

(1) The HEE structure shall be grounded in accordance with NFPA 70.

(2) All conductive parts of the enclosure shall be grounded or bonded.

(3) Hydrogen piping and equipment shall be bonded to the HEE structure to prevent static discharge.

7.1.23.3

GH2 shall not be vented within the HEE or to compartments within a HEE.

7.1.23.3.1

Vent pipes shall be in accordance with Section 7.1.17.3.

7.1.23.3.2

Pressure relief devices and valves discharging to the atmosphere shall be vented in accordance with 7.1.5.5.5.

7.1.23.4

A HEE that can be entered and contains or is connected to a source of GH2 shall be evaluated for the potential of an oxygen-deficient atmosphere during

normal or off-normal conditions.

7.1.23.4.1

Where the potential exists for an oxygen-deficient atmosphere, detection and notification appliances shall be provided to warn personnel of an oxygen-deficient atmosphere.

7.1.23.4.1.1

Notification appliances shall produce a distinctive audible and visual alarm and be located outside the entrance to all locations where the oxygen-deficientcondition could exist.


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7.1.23.4.1.2

If a GH2 detection system is provided in accordance with Section 6.12, oxygen detectors are not required.

7.1.23.5 Security.

7.1.23.5.1

Exterior access doors for a HEE shall be secured against unauthorized entry.

7.1.23.5.1.1

Exterior access doors shall not be required to be secured if a secured perimeter fence or wall is provided to prevent unauthorized entry.

7.1.23.5.2

Locks or latches shall not require the use of a key, a tool, or special knowledge or effort for the operation from the egress side.

7.1.23.6*

Means of egress for a HEE shall be in accordance with 7.1.23.6.1, unless the HEE cannot be entered.

7.1.23.6.1

Not fewer than two means of egress shall be provided from each equipment enclosure or equipment compartment, unless all of the following criteria aremet:

(1) Undivided HEE or equipment compartments do not exceed 200 ft2 (18.6 m2), and

(2) HEE or equipment compartments have a travel distance to the room or compartment exit door(s) not exceeding 15 ft (4.6 m).

7.1.23.6.1.1

The means of egress shall have:

(1) A minimum of 28 in. (710 mm) clear width, and

(2) A minimum headroom of not less than 6 ft, 8 in. (2030 mm) along the entire designated means of egress path

7.1.23.7

Hydrogen piping and equipment shall be isolated, depressurized, and made safe prior to replacement.

7.1.23.8

A HEE shall be secured to a structure or foundation in a manner approved by the AHJ.

7.1.23.9 Isolation of GH2 Storage.

7.1.23.9.1

Where required by Table 7.1.23.9.1, a means for isolation of GH2 storage shall be provided in accordance with 7.1.23.9.

Table 7.1.23.9.1 Protection Features Based on Use

HEE or a compartment in aHEE contains:

GH2 storage GH2 storageHydrogen generation,compression and/or

processing equipment

Support equipment room(in an HEE)

Enclosure Volume: <200 ft3 ≥200 ft3 Not limited Not limited

Contains or is connected to asource of hydrogen:

Yes Yes Yes No

Automatic isolation from GH2storage

Not required Not required Required Not applicable

Ventilation Natural or mechanical Natural for 3-wallsHEE/mechanical for 4-wallsHEE

Mechanical No additional requirement

Storage compartment separation Not applicable Not applicable Required Required

Electrical equipment Per NFPA 70, Chapter 5 Per NFPA 70, Chapter 5 Per NFPA 70, Chapter 5 Unclassified

Bonding/grounding Required Required Required Per NFPA 70

Explosion control Not required Required Required Not required

Detection Loss of ventilation* GH2, Loss of ventilation* GH2, Fire and Loss of

ventilation

GH2 if necessary to meet the

requirements of7.1.23.10.3.1

*When mechanical ventilation is provided

7.1.23.9.2*

GH2 storage shall be equipped with automatic emergency shutoff valves to isolate the source of hydrogen from the delivery piping system.

7.1.23.9.3

Automatic emergency shutoff valves shall be located within the same compartment as the hydrogen storage.

7.1.23.9.4

Automatic emergency shutoff valves shall operate on GH2 detection alarms, fire alarms, and emergency shutdown system activations.

7.1.23.9.5

Automatic emergency shutoff valves shall be fail-safe to close upon loss of power or air pressure.

7.1.23.9.6

GH2 generation and compression equipment within a HEE which supplies hydrogen to storage containers shall be equipped with either an external

automatic emergency shutoff valve or non-return valve on the exit piping outside the enclosure or compartment.

7.1.23.10 Ventilation.


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7.1.23.10.1

Where required by Table 7.1.23.9.1, ventilation shall be provided in accordance with 7.1.23.10.

7.1.23.10.2

A HEE and compartments within a HEE that contain GH2 storage, equipment, or piping shall be provided with ventilation in accordance with 7.3.2.2.2.2.

7.1.23.10.3

Natural ventilation openings and air intakes for mechanical ventilation systems shall be separated from non-bulk sources of GH2 in accordance with

7.2.2.3.2.2 and from bulk sources of GH2 in accordance with 7.3.2.3.1.1.

7.1.23.10.3.1

Air intakes and ventilation openings shall not be required to meet the requirements of 7.1.23.10.3 where the compartment is provided with GH2 detection

in accordance with 7.1.23.14, which deactivates power to all electrical equipment within the enclosure upon detection of 25 percent of the LFL.

7.1.23.11 Storage Area Separation.

7.1.23.11.1

Where required by Table 7.1.23.9.1, storage area separation shall be provided in accordance with 7.1.23.11.

7.1.23.11.2

Fuel cell equipment, compressors, hydrogen generators, electrical distribution equipment, and similar appliances shall be separated from GH2 storage

areas within the HEE by a one-hour fire rated barrier that is also capable of preventing gas transmission.

7.1.23.12 Electrical Equipment.

7.1.23.12.1

All electrical equipment in a HEE that has GH2 piping, storage, generation, or processing equipment shall be in accordance with Chapter 5 of NFPA 70.

7.1.23.12.2

Electrical equipment within 15 ft (4.6 m) of any natural ventilation opening or required exhaust discharge of a HEE shall comply with the requirements ofChapter 5 of NFPA 70.

7.1.23.13 Emergency Shutdown System.

7.1.23.13.1

An emergency shutdown system (ESS) shall be provided for the HEE.

7.1.23.13.1.1

The ESS shall operate on GH2 detection alarms, fire alarms, and loss of ventilation alarms, where these are required by Table 7.1.23.9.1.

7.1.23.13.1.2

The ESS shall operate upon activation of a manual emergency shutdown device (ESD).

7.1.23.13.1.3

The ESS shall operate across all interconnected HEE at a common site.

7.1.23.13.1.4

Where activated, the ESS shall de-energize unclassified electrical equipment inside compartments containing hydrogen or other flammable gases andclose all automatic shutoff control valves on piping into and from interconnected HEE and HEE compartments containing hydrogen equipment.

7.1.23.13.1.5

A manual ESD shall be located on the exterior of each HEE that is interconnected to the hydrogen system.

(A)

The ESD shall be identified by a sign located at the exterior of the equipment enclosure.

7.1.23.13.1.6

A remote emergency shutdown shall be located not less than 25 ft (7.6 m) and not more than 100 ft (30 m) from HEE equipped with individual ESDs.

7.1.23.14 Detection.

7.1.23.14.1

Where required by Table 7.1.23.9.1, GH2 detection, fire detection, and loss of ventilation detection shall be provided in accordance with 7.1.23.14.

7.1.23.14.2

GH2 detection shall be provided in accordance with Section 6.12.

7.1.23.14.2.1

Detection of hydrogen above 25 percent of the LFL shall result in activation of the ESS, and shall be indicated by a visible notification device mounted onthe exterior of the HEE.

7.1.23.14.3

Heat detectors or flame detectors shall be provided and installed in accordance in NFPA 72.

7.1.23.14.4

A device shall be provided to detect failure of the ventilation system.

7.1.23.14.4.1

The device shall activate the ESS when airflow drops below 75 percent of the required flow.

7.1.23.15 Explosion Control.

7.1.23.15.1

Where required by Table 7.1.23.9.1, explosion control shall be provided in accordance with Section 6.9.

7.1.23.15.1.1

Explosion vents, where used, shall not discharge into adjacent HEE compartments.


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7.1.24 Emergency Shutoff Valves.

7.1.24.1

Accessible manual or automatic emergency shutoff valves shall be provided to shut off the flow of GH2 in case of emergency. [55:7.3.1.11.1]

7.1.24.1.1*

Manual emergency shutoff valves or the device that activates an automatic emergency shutoff valve on a bulk source or piping systems serving the bulksupply shall be identified by means of a sign. [55:7.3.1.11.1.1]

7.1.24.2

Emergency shutoffs shall be located at the point of use and at the tank, cylinder, or bulk source,and at the point where the system piping enters thebuilding. [55:7.3.1.11.2]

7.1.25 Emergency Isolation.

7.1.25.1

Where [GH2] [-] is carried in pressurized piping above a gauge pressure of 15 psi (103 kPa), an approved means of emergency isolation shall be provided

[-]. [55:7.3.1.12.1]

7.1.25.2

Approved means of meeting the requirements for emergency isolation shall include any of the following:

(1) Automatic shutoff valves located as close to the bulk source as practical tied to leak detection systems.

(2) Attended control stations where trained personnel can monitor alarms or supervisory signals and can trigger emergency responses.

(3) A constantly-monitored control station with an alarm and remote shutoff of the gas supply system.

(4) Excess flow valves at the bulk source.

[55:7.3.1.12.2

7.1.25.3

The requirements of7.1.25 shall not be required for the following:

(1) Piping for inlet connections designed to prevent backflow at the source

(2) Piping for pressure relief devices

(3) Where the source of the gas is not in excess of the quantity threshold indicated in Table 6.4.1.1

[55:7.3.1.12.3]

7.1.25.4 Location Exemptions.

The requirements of 7.1.25.1 shall not apply to the following:

(1) Piping for inlet connections designed to prevent backflow


(3) Systems containing 430 scf (12.7 Nm3) or less of [GH2]

[55:7.3.1.12.4]

7.1.26 Ignition Source Control.

Ignition sources in areas containing [GH2] shall be in accordance with 7.1.26. [55:7.6.3]

7.1.26.1 Static Producing Equipment.

Static producing equipment located in [GH2] areas shall be grounded. [55:7.6.3.1]

7.1.26.2 No Smoking or Open Flame.

Signs shall be posted in areas containing [GH2] stating that smoking or the use of open flame, or both, is prohibited within 25 ft (7.6 m) of the storage or

use area perimeter. [55:7.6.3.2]

7.1.27 Operating Instructions.

(A)

For installations that require any operation of equipment by the user, the user shall be instructed in the operation of the equipment and emergencyshutdown procedures. [55:10.2.6.1.1]

(B)

Instructions shall be maintained at the operating site at a location acceptable to the authority having jurisdiction. [55:10.2.6.1.2]

7.1.28 Maintenance.

7.1.28.1

Maintenance shall be performed annually by a qualified representative of the equipment owner. [55:10.2.6.2.1]

7.1.28.2

The maintenance shall include inspection for physical damage, leak tightness, ground system integrity, vent system operation, equipment identification,warning signs, operator information and training records, scheduled maintenance and retest records, alarm operation, and other safety-related features.[55:10.2.6.2.2]

7.1.28.3

Scheduled maintenance and retest activities shall be formally documented and records shall be maintained a minimum of 3 years. [55:10.2.6.2.3]

7.2 Non-Bulk GH2.

7.2.1 Non-Bulk GH2 General.

7.2.1.1* Incompatible Materials.


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[GH2] cylinders, containers, and tanks shall be separated in accordance with Table 7.2.1.1. [55:7.1.10.2]

Table 7.2.1.1 Separation of Gas Cylinders, Containers, and Tanks by Hazard Class [from Non-Bulk GH2 Cylinders, Containers, Tanks, and Systems]

GH2a

Gas Category ft m

Toxic or highly toxic 20 6.1

Pyrophoric 20 6.1

Flammable — —

Oxidizing 20 6.1

Corrosive 20 6.1

Unstable reactive Class 2, Class 3, or Class 4 20 6.1

Other gas NR NR

NR: No separation required.

[55:7.1.10.2]

aExtract of flammable gas column from Table 7.1.10.2 of NFPA 55.

7.2.1.1.1

GH2 systems in outdoor storage or use shall be separated from other compressed gases in accordance with Table 7.3.2.3.1.1(a).

7.2.1.1.2

Subparagraph 7.2.1.1.1 shall not apply to [GH2] contained within closed piping systems. [55:7.1.10.2.1]

7.2.1.1.3

The distances shown in Table 7.2.1.1 shall be permitted to be reduced without limit [when GH2] cylinders, containers, and tanks are separated by a barrier

of noncombustible construction that has a fire resistance rating of at least 0.5 hour and interrupts the line of sight between the containers. [55:7.1.10.2.2]

7.2.1.1.4

The 20 ft (6.1 m) distance shall be permitted to be reduced to 5 ft (1.5 m) where one of the gases is enclosed in a gas cabinet or without limit where bothgases are enclosed in gas cabinets. [55:7.1.10.2.3]

7.2.1.1.5

Cylinders without pressure relief devices shall not be stored without separation from flammable and pyrophoric gases with pressure relief devices.[55:7.1.10.2.4]

7.2.1.1.6

Spatial separation shall not be required between cylinders deemed to be incompatible in gas production facilities where cylinders are connected tomanifolds for the purposes of filling, analysis of compressed gases, or manufacturing procedures, assuming the prescribed controls for the manufacture ofgas mixtures are in place. [55:7.1.10.2.5]


The hydrogen compressed gas system shall be electrically bonded and grounded. [55:10.3.2]

7.2.1.2.1

Mobile hydrogen supply units shall be electrically bonded to the storage system before hydrogen is discharged from the supply unit. [55:10.3.2.1]

7.2.2 Non-Bulk GH2 Storage.

7.2.2.1 General.

7.2.2.1.1 Applicability.

The storage of [GH2] exceeding the quantity thresholds for gases requiring special provisions as specified in Table 6.4.1.1 shall be in accordance with

Chapters 1 through 6 [as applicable] and Sections 7.1 through 7.2. [55:7.6.1.1]

7.2.2.1.2 Classification of Weather Protection as an Indoor Versus Outdoor Area.

For other than explosive materials and hazardous materials presenting a detonation hazard, a weather protection structure shall be permitted to be usedfor sheltering outdoor storage or use areas without requiring such areas to be classified as indoor storage. [55:7.2.1.3]

7.2.2.2 Indoor Storage.

Indoor storage of [GH2] shall be in accordance with the [applicable] provisions of Section 7.1. [55:7.2.2.1]

7.2.2.2.1

Indoor GH2 systems in control areas with less than the maximum allowable quantities per control area shown in Table 6.4.1.1 shall be located in

accordance with the applicable provisions of Table 7.3.2.2.1.

7.2.2.2.2 Indoor Hydrogen System Location.


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7.2.2.2.2.1

Hydrogen systems of less than 5000 scf (141.6 Nm3) and greater than the MAQ, where located inside buildings, shall be in accordance with the following:

(1) In a ventilated area in accordance with the provisions of Section 6.17

(2) Separated from incompatible materials in accordance with the provisions of 7.2.1.1

(3) A distance of 25 ft (7.6 m) from open flames and other sources of ignition

(4) A distance of 50 ft (15 m) from intakes of ventilation, air-conditioning equipment, and air compressors located in the same room or area as thehydrogen system

(a) The distance shall be permitted to be reduced to 10 ft (3.1 m) where the room or area in which the hydrogen system is installed is protected by alisted detection system as per Article 500.7(K) of NFPA 70 and the detection system shall shut down the fuel supply in the event of a leak thatresults in a concentration that exceeds 25 percent of the LFL.

(b) Emergency shutoff valves shall be provided in accordance with 7.1.24.

(5) A distance of 50 ft (15 m) from other flammable gas storage

(6) Protected against damage in accordance with the provisions of 7.1.7.3

[55:10.3.4.1]

7.2.2.2.2.2 Systems Installed in One Room.

(A)

More than one system of 5000 scf (141.6 Nm3) or less shall be permitted to be installed in the same room or area, provided the systems are separated byat least 50 ft (15 m) or a full-height fire-resistive partition having a minimum fire resistance rating of 2 hours is located between the systems. [55:10.3.4.2.1]

(B)

The separation distance between multiple systems of 5000 scf (141.6 Nm3) or less shall be permitted to be reduced to 25 ft (7.6 m) in buildings where thespace between storage areas is free of combustible materials and protected with a sprinkler system designed for Extra Hazard, Group 1 in accordancewith the requirements of Section 6.10 . [55:10.3.4.2.2]

(C)

The required separation distance between individual portable systems in the process of being filled or serviced in facilities associated with the manufactureor distribution of hydrogen and its mixtures shall not be limited by 7.2.2.2.2.2(A) or 7.2.2.2.2.2(B) when such facilities are provided with Protection Level 2controls and the applicable requirements of Chapters 1 through 7. [55:10.3.4.2.3]

7.2.2.3 Outdoor Storage.

7.2.2.3.1 General.

Exterior storage of [GH2] shall be in accordance with 7.2.1, 7.2.2.1, and 7.2.2.3. [55:7.2.2.2.1]

7.2.2.3.2 Distance to Exposures.

The outdoor storage or use of [GH2] shall be located from lot lines, public streets, public alleys, public ways, or buildings not associated with the

manufacture or distribution of [GH2] in accordance with Table 7.2.2.3.2. [55:7.6.2]

Table 7.2.2.3.2 Distance to Exposures for Non–Bulk [GH2]

Maximum AmountPer Storage Area

(ft3)

MinimumDistance Between

Storage Areas

(ft)

Minimum Distance toLot Lines of Property

That Can Be Built Upon

(ft)

Minimum Distance toPublic Streets, PublicAlleys, or Public Ways

(ft)

Minimum Distance to Buildings on the SameProperty

Less Than 2-HourConstruction

2-HourConstruction

4-HourConstruction

0–4225 5 5 5 5 0 0

4226–21,125 10 10 10 10 5 0

21,126–50,700 10 15 15 20 5 0

50,701–84,500 10 20 20 20 5 0

84,501–200,000 20 25 25 20 5 0

For SI units: 1 ft = 304.8 mm; 1 scf = 0.02832 Nm3.

Note: The minimum required distances shall not apply when fire barriers without openings or penetrations having a minimum fire resistive rating of 2 hoursinterrupt the line of sight between the storage and the exposure. The configuration of the fire barriers shall be designed to allow natural ventilation toprevent the accumulation of hazardous gas concentrations.

[55: Table 7.6.2]

7.2.2.3.2.1 Fire Barriers.

(A)*

Where a fire barrier is used to protect [GH2] systems, the system shall terminate downstream of the source valve. [55:7.5.2.1.1]

(B)

The fire barrier wall shall be either an independent structure or the exterior wall of the building adjacent to the storage or use area. [55:7.5.2.1.2]

(C)

The fire barrier wall shall be without openings or penetrations. [55:8.7.2.1.1]

(1) Penetrations of the fire barrier wall by conduit or piping shall be permitted provided that the penetration is protected with a firestop system inaccordance with the [adopted] building code. [55:8.7.2.1.1.1]

(D)

The configuration of the [fire barrier] shall be designed to allow natural ventilation to prevent the accumulation of hazardous gas concentrations.[55:7.6.2.3]

7.2.2.3.2.2 Air Intakes.

Storage and use of [GH2] shall not be located within 50 ft (15.2 m) of air intakes. [55:7.6.2.4]


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7.2.2.3.2.3 Building Openings.

Storage and use of [GH2] outside of buildings shall also be separated from building openings by 25 ft (7.6 m). Fire barriers shall be permitted to be used as

a means to separate storage areas from openings or a means of egress used to access the public way. [55:7.6.2.5]

7.2.3 Non-Bulk GH2 Use.

7.2.3.1 General.


The storage or use of [GH2] exceeding the quantity thresholds for gases requiring special provisions as specified in Table 6.4.1.1 shall be in accordance

with Chapters 1 through 6 [as applicable] and Sections 7.1 and 7.2. [55:7.6.1.1]

7.2.3.2 Indoor Use.

Indoor use of [GH2] shall be in accordance with the requirements of Section 7.1. [55:7.3.2.1]

7.2.3.3 Outdoor Use.

Exterior use of [GH2] shall be in accordance with the [applicable] requirements of Section 7.1. [55:7.3.2.2.1]

7.2.4 Non-Bulk GH2 Handling.

7.2.4.1 Applicability.



7.2.4.2 Carts and Trucks.

7.2.4.2.1

Cylinders, containers, and tanks shall be moved using an approved method. [55:7.3.3.2.1]

7.2.4.2.2

Where cylinders, containers, and tanks are moved by hand cart, hand truck, or other mobile device, such carts, trucks, or devices shall be designed for thesecure movement of cylinders, containers, and tanks. [55:7.3.3.2.2]

7.2.4.3 Lifting Devices.

Ropes, chains, or slings shall not be used to suspend [GH2] cylinders, containers, and tanks unless provisions at time of manufacture have been made on

the cylinder, container, or tank for appropriate lifting attachments, such as lugs. [55:7.3.3.3]

7.2.4.4 Cargo Transport Unloading.

Cargo transport unloading shall be in accordance with 7.3.4.2.

7.3 Bulk GH2 Systems.

7.3.1 Bulk GH2 Systems — General.

7.3.1.1 Applicability.

The storage, use, and handling of bulk [GH2] systems shall be in accordance with the applicable provisions of Chapters 1 through 6, and Section 7.3.

[55:10.1]

7.3.1.2

7.3.1.2.1 Bonding and Grounding.

The [bulk] hydrogen compressed gas system shall be electrically bonded and grounded. [55:10.3.2]

7.3.2 Bulk GH2 Systems Storage.

7.3.2.1 General Requirements.

7.3.2.1.1

Systems located above ground either at grade or above grade shall be in accordance with 7.3.2. [55:10.4.2]

7.3.2.1.2* Fire Protection.

Fire protection shall be in accordance with the requirements of Section 6.10. [55:10.4.5.1.2]

7.3.2.1.3 Installation in Vaults Above and Below Ground.

Generation, compression, storage and dispensing equipment for compressed gases shall be allowed to be located in either abovegrade or belowgradevaults in accordance with IFC 5303.16.


7.3.2.2.1

The location of bulk [GH2] systems shall be in accordance with Table 7.3.2.2.1. [55:10.4.5.1.1].

Table 7.3.2.2.1 Location of [GH2] Systems

Quantity of Hydrogen

Location ≥5000 scf to <15,000 scf (≥142Nm3 to <425 Nm3) ≥15,000 scf (≥425 Nm3)

In a detached building A A

In a gas room, in accordance with Section 6.4 A Detached building required

Not in a gas room NA Detached building required

A: Allowed. NA: Not allowed.

[55: Table 10.4.5.1.1]

7.3.2.2.2 Detached Buildings.


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7.3.2.2.2.1

Detached buildings shall be constructed of noncombustible or limited-combustible materials in accordance with the requirements of Section 6.5.[55:10.4.5.2.1]

7.3.2.2.2.2

Ventilation shall be provided in accordance with the requirements of Section 6.17. [55:10.4.5.2.2]

(A)

Outlet openings shall be located at the high point of the room in exterior walls or roof. [55:10.4.5.2.2.1]

(B)

Inlet and outlet openings shall each have a minimum total area of 1 ft2/1000 ft3 (1 m2/305 m3) of room volume. [55:10.4.5.2.2.2]

(C)

Discharge from outlet openings shall be directed or conducted to the atmosphere. [55:10.4.5.2.2.3]

7.3.2.2.2.3*

Explosion control shall be provided in accordance with the requirements of Section 6.9. [55:10.4.5.2.3]

7.3.2.2.2.4

Electrical equipment shall be in accordance with Article 501 of NFPA 70 for Class I, Division 2 locations. [55:10.4.5.2.4]

7.3.2.2.2.5

Heating, if provided, shall be by steam, hot water, or other indirect means except that electrical heating shall be permitted to be used if in compliance with7.3.2.2.2.4. [55:10.4.5.2.5]

7.3.2.2.3 Hydrogen Gas Rooms.

7.3.2.2.3.1

Floors, walls, and ceilings shall be constructed of noncombustible or limited-combustible materials in accordance with the requirements of the [adopted]building code. [55:10.4.5.3.1]

(A)

Interior walls or partitions shall have a fire resistance rating of not less than 2 hours, shall be continuous from floor to ceiling, and shall be anchored toresist movement. [55:10.4.5.3.1.1]

(B)

Not less than 25 percent of the perimeter wall shall be an exterior wall. [55:10.4.5.3.1.2]

(C)

Openings to other parts of the building shall not be permitted. [55:10.4.5.3.1.3]

(D)

Windows and doors shall be in exterior walls only. [55:10.4.56.3.1.4]

7.3.2.2.3.2

Ventilation shall be as provided in 6.17. [55:10.4.5.3.2]

7.3.2.2.3.3


7.3.2.2.3.4

There shall be no sources of ignition from open flames, electrical equipment, or heating equipment. [55:10.4.5.3.4]

7.3.2.2.3.5*


7.3.2.2.3.6

Heating, if provided, shall be by steam, hot water, or indirect means except that electrical heating shall be permitted to be used if in compliance with7.3.2.2.3.5. [55:10.4.5.3.6]

7.3.2.3 Outdoor Storage.

7.3.2.3.1 Aboveground Locations.


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7.3.2.3.1.1* Minimum Distance for Aboveground Locations.


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The minimum distance from a [GH2] system located outdoors to specified exposures shall be in accordance with Table 7.3.2.3.1.1(a),Table 7.3.2.3.1.1(b)

or Table 7.3.2.3.1.1(c) . [55:10.4.2.2.1]

(1) Maximum Internal Diameter of Interconnecting Piping. The maximum internal diameter of the piping system used for interconnecting pipingbetween the shutoff valve on any single storage container to the point of connection to the system source valve shall not be required to be inaccordance with the values shown in Table 7.3.2.3.1.1(a) when in accordance with Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c) . [55:10.4.2.2.2]

(a) The separation distance for piping systems with internal diameters other than those specified in Table 7.3.2.3.1.1(a) for the pressure rangeselected shall be permitted with tabular distances determined based on the use of the equations in Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c) .[55:10.4.2.2.1.1]

(b) Separation distances determined based on the use of Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c) shall be subject to review and approval by theAHJ. [55:10.4.2.2.2.2]

(c)

(d)

Table 7.3.2.3.1.1(a) Minimum Distance (D) from Outdoor [GH2] Systems to Exposures — Typical Maximum Pipe Size

Pressure> 15 to ≤250 psig

> 250 to ≤3000 psig

> 3000 to ≤7500 psig

> 7500 to ≤15000 psig

Internal Pipe Diameter (ID)>103.4 to ≤1724 kPa

>1724 to ≤20,684 kPa

>20,684 to ≤51,711 kPa

>51,711 to ≤103,421 kPa

dmm d = 52.5mm d = 18.97mm d = 7.31mm d = 7.16mm

Exposures Group 1 m ft m ft m ft m ft

(a) Lot lines 12 40 14 46 9 29 10 34

(b) Air intakes (HVAC, compressors, other)

(c) Operable openings in buildings and structures

(d) Ignition sources such as open flames and welding


(a) Exposed persons other than those servicing the system 6 20 7 24 4 13 5 16

(b) Parked cars


(a) Buildings of non-combustible non-fire-rated construction 5 17 6 19 4 12 4 14

(b) Buildings of combustible construction

(c) Flammable gas storage systems above or below ground

(d) Hazardous materials storage systems above or below ground

(e) Heavy timber, coal, or other slow-burning combustible solids

(f) Ordinary combustibles, including fast-burning solids such as ordinary lumber,excelsior, paper, or combustible waste and vegetation other than that found inmaintained landscaped areas

(g) Unopenable openings in building and structures

(h) Encroachment by overhead utilities (horizontal distance from the vertical planeBelow the nearest overhead electrical wire of building service)

(i) Piping containing other hazardous materials

(j) Flammable gas metering and regulating stations such as natural gas or propane.

[55:Table 10.4.2.2.1(a)]

Table 7.3.2.3.1.1(b) Minimum Distance (D) from Outdoor [GH2] Systems to Exposures by Maximum Pipe Size with Pressures >15 to ≤3000 psig

Pressure

>15 to ≤250 psig

>103.4 to ≤1724 kPa

>250 to ≤3000 psig

>17.24 to ≤20,684 kPa

Exposures*† Exposures*†

Internal PipeDiameter (ID)

Group 1 Group 2 Group 3 Group 1 Group 2 Group 3

D = 0.231dD = 0.12584d −

0.47126D = 0.096d D = 0.738d

D = 0.43616d −0.91791

D = 0.307d

ID (in.) d (mm) m ft m ft m ft m ft m ft m ft

0.2 5.1 1 4 0 1 0 2 4 12 1 4 2 5

0.3 7.6 2 6 0 2 1 2 6 18 2 8 2 8

0.4 10.2 2 8 1 3 1 3 7 25 4 12 3 10

0.5 12.7 3 10 1 4 1 4 9 31 5 15 4 13

0.6 15.2 4 12 1 5 1 5 11 37 6 19 5 15

0.7 17.8 4 13 2 6 2 6 13 43 7 22 5 18

0.8 20.3 5 15 2 7 2 6 15 49 8 26 6 20

0.9 22.9 5 17 2 8 2 7 17 55 9 30 7 23

1.0 25.4 6 19 3 9 2 8 19 62 10 33 8 26

1.1 27.9 6 21 3 10 3 9 21 68 11 37 9 28

* Determination of Internal Diameter. The internal diameter of the piping system shall be determined by the diameter of the piping serving that

portion of a storage array with content greater than 5000 scf (141.6 Nm3). The piping system size used in the application of Table 7.3.2.3.1.1(a),Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c)and shall be determined based on that portion of the system with the greatest maximum internaldiameter. [55:10.4.2.2.2.1]

* Determination of System Pressure. The system pressure shall be determined by the maximum operating pressure of the storage array with

content greater than 5000 scf (141.6Nm3), irrespective of those portions of the system elevated to a higher pressure. [55:10.4.2.2.3]


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Pressure

>15 to ≤250 psig

>103.4 to ≤1724 kPa

>250 to ≤3000 psig

>17.24 to ≤20,684 kPa




D = 0.231dD = 0.12584d −

0.47126D = 0.096d D = 0.738d

D = 0.43616d −0.91791

D = 0.307d

1.2 30.5 7 23 3 11 3 10 22 74 12 41 9 31

1.3 33 8 25 4 12 3 10 24 80 13 44 10 33

1.4 35.6 8 27 4 13 3 11 26 86 15 48 11 36

1.5 38.1 9 29 4 14 4 12 28 92 16 52 12 38

1.6 40.6 9 31 5 15 4 13 30 98 17 55 12 41

1.7 43.2 10 33 5 16 4 14 32 105 18 59 13 43

1.8 45.7 11 35 5 17 4 14 34 111 19 62 14 46

1.9 48.3 11 37 6 18 5 15 36 117 20 66 15 49

2.0 50.8 12 39 6 19 5 16 37 123 21 70 16 51

2.1 53.3 12 40 6 20 5 17 39 129 22 73 16 54

Note: Linear interpolation of internal pipe diameters and distances between table entries is allowed.

*For a list of exposures in each exposure group see Column 1 of Table 7.3.2.3.1.1(a).

†When calculating the minimum separation distance (D) using the formulas indicated, based on the exposure group and pressure indicated, the internalpipe diameter (d) is entered in millimeters (mm). The calculated distance (D) is expressed in units of measure in meters (m). To convert distance (D) tounits of measure in feet, multiply the value of (D) in meters by 3.2808 and round to the nearest whole foot.

[55:Table 10.4.2.2.1(b)]

Table 7.3.2.3.1.1(c) Minimum Distance (D) from Outdoor [GH2] Systems to Exposures by Maximum Pipe Size with Pressures >3000 to ≤15,000 psig

Pressure

>3000 to ≤7500 psig

>20,684 to ≤51,711 kPa

>7500 to ≤15,000 psig

>51,711 to ≤103,421 kPa




ID (in.) d (mm)

D = 1.105dD = 0.68311d −

1.3123 D = 0.459d D = 1.448d D = 1.448d D = 0.602d

m ft m ft m ft m ft m ft m ft

0.2 5.1 6 18 2 7 2 8 7 24 3 10 3 10

0.3 7.6 8 28 4 13 3 11 11 36 5 18 5 15

0.4 10.2 11 37 6 18 5 15 15 48 8 25 6 20

0.5 12.7 14 46 7 24 6 19 18 60 10 33 8 25

0.6 15.2 17 55 9 30 7 23 22 72 12 41 9 30

0.7 17.8 20 64 11 36 8 27 26 84 15 49 11 35

0.8 20.3 22 74 13 41 9 31 29 97 17 56 12 40

0.9 22.9 25 83 14 47 10 34 33 109 20 64 14 45

1.0 25.4 28 92 16 53 12 38 37 121 22 72 15 50

1.1 27.9 31 101 18 58 13 42 40 133 24 80 17 55

1.2 30.5 34 111 20 64 14 46 44 145 27 87 18 60

1.3 33.0 36 120 21 70 15 50 48 157 29 95 20 65

1.4 35.6 39 129 23 75 16 54 51 169 31 103 21 70

1.5 38.1 42 138 25 81 17 57 55 181 34 111 23 75

1.6 40.6 45 147 26 87 19 61 59 193 36 118 24 80

1.7 43.2 48 157 28 92 20 65 63 205 38 126 26 85

1.8 45.7 51 166 30 98 21 69 66 217 41 134 28 90

1.9 48.3 53 175 32 104 22 73 70 229 43 142 29 95

2.0 50.8 56 184 33 110 23 77 74 241 46 149 31 100




[55:Table 10.4.2.2.1(c)]

7.3.2.3.1.2* Reduction of Distance by Mitigation Means.


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(A)*

Except for distances to air intakes, the distances to Group 1 and 2 exposures shown in Table 7.3.2.3.1.1(a) ,Table 7.3.2.3.1.1(b) and Table 7.3.2.3.1.1(c)shall be permitted to be reduced by one-half and shall not apply to Group 3 exposures where fire barrier walls are located between the system and theexposure and constructed in accordance with the following: [55:10.4.2.2.4.1]

(1) The fire barrier wall shall be without openings or penetrations. [55:8.7.3.2.1]

(a) Penetrations of the fire barrier wall by conduit or piping shall be permitted provided that the penetration is protected with a firestop system inaccordance with the [adopted] building code. [55:8.7.3.2.1.1]

(2) Fire barrier walls shall have a minimum fire resistance rating of not less than 2 hours. [55:10.4.2.2.4.1(1)]

(3) The fire barrier wall shall interrupt the line of sight between the bulk hydrogen compressed gas system and the exposure. [55:10.4.2.2.4.1(2)]

(4) The configuration of the fire barrier shall allow natural ventilation to prevent the accumulation of hazardous gas concentrations. [55:10.4.2.2.4.1(3)]

(5) The number of fire barrier walls used to separate individual systems shall be limited to three. [55:10.4.2.2.4.1(4)]

(6) The fire barrier wall shall not have more than two sides at 90 degrees (1.57 rad) directions or not more than three sides with connecting angles of 135degrees (2.36 rad). [55:10.4.2.2.4.1(5)]

(a) The connecting angles between fire barrier walls shall be permitted to be reduced to less than 135 degrees (2.3 rad) for installations consisting ofthree walls when in accordance with 8.3.2.3.1.5(E). [55:10.4.2.2.4.1(5)(a)]

(7) Fire barrier walls shall be designed and constructed as a structure in accordance with the requirements of the building code without exceeding thespecified allowable stresses for the materials of construction utilized. Structures shall be designed to resist the overturning effects caused by lateralforces due to wind, soil, flood, and seismic events. [55:10.4.2.2.4.1(6)]

(8) Where clearance is required between bulk hydrogen compressed gas system and the barrier wall for the performance of service or maintenance-related activities, a minimum horizontal clearance of 5 ft (1.5 m) shall be provided between the structure and the system. [55:10.4.2.2.4.1(7)]

(9) The fire barrier wall shall be either an independent structure or the exterior wall of the building adjacent to the storage or use area when the exteriorbuilding wall meets the requirements for fire barrier walls. [55:10.4.2.2.4.1(8)]

(B)* Active Means.

Active control systems that mitigate the rise of system leaks and failures shall be permitted to be used as a means to reduce separation distances whereapproved by the AHJ under the authority as granted by Section 1.5. [55:10.4.2.2.4.2]

7.3.2.3.1.3 Required Separation Distance for All Systems.

Separation distances shall be required for bulk hydrogen compressed gas systems independent of system pressure or internal diameter of piping systemsin accordance with Sections 7.3.2.3.1.3(A) through 7.3.2.3.1.3(C). [55:10.4.2.2.5]

(A)

Unloading connections on delivery equipment shall not be positioned closer to any of the exposures cited in Table 7.3.2.3.1.1(a) , Table 7.3.2.3.1.1(b) , orTable 7.3.2.3.1.1(c) than the distances given for the storage system. [55:10.4.2.2.5]

(B)

The minimum separation distance between gaseous and liquid systems integrated into a single system where the liquid source is vaporized, compressed,and stored in the gaseous state shall be 15 ft (4.6 m). [55:10.4.2.2.5.2]

(C)

Systems within 50 ft (15 m) of aboveground storage of all classes of flammable and combustible liquids shall be located on ground higher than suchstorage, except where dikes, diversion curbs, grading, or separating solid walls are used to prevent accumulation of the liquids under the system.[55:10.4.2.2.5.3]

7.3.2.3.1.4

Bulk hydrogen compressed gas systems shall be allowed to integrate or co-locate other nonliquefied flammable gas systems as a component of thehydrogen gas system without separation, where the output of the system is designed to deliver a product in which the gases are mixed or blended fordelivery into the user’s system. [55:10.4.2.2.6]

7.3.2.3.1.5 Electrical Equipment.

Electrical wiring and equipment shall be in accordance with Article 500 of NFPA 70. [55:10.4.2.1.2]

Table 7.3.2.3.1.5 Electrical Area Classification

Location Classification Extent of Classified Area

Within 3 ft (1 m) of any vent outlet and anypoints where hydrogen is vented to theatmosphere under normal conditions

Class 1, Division 1Between 0 ft (0 m) and 3 ft (0.9 m) and measuredspherically from the outlet.

Between 3 ft (1 m) and 15 ft (4.6 m) of anyvent outlet and any points where hydrogen isvented to the atmosphere under normaloperations.

Class I, Division 2Between 3 ft (0.9 m) and 15 ft (4.6 m) and measuredspherically from the vent outlet

Storage equipment excluding the pipingsystem downstream of the source valve

Class I, Division 2Between 0 ft (0 m) and 15 ft (4.6 m) and measuredspherically from the source

7.3.2.4 Underground Systems.

Bulk hydrogen compressed gas systems installed underground where [GH2] containers are to be buried in contact with earth or fill shall be in accordance

with 7.3.2.4. [55:10.4.3.1]

7.3.2.4.1 Container Design.

Pressure [GH2] containers installed underground using burial methods shall be of seamless construction in accordance with Part UF or Appendix 22 of the

ASME Boiler and Pressure Vessel Code, Section VIII, Division 1. [55:10.4.3.1.1]

7.3.2.4.1.1*

[GH2] containers shall be designed to include cyclic pressure life calculations using fracture mechanics methods. [55:10.4.3.1.1.1]

7.3.2.4.1.2 GH2 Container Examination.


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(A)

[GH2] containers shall be examined for internal and external surface flaws and inclusions before burial, or at the time of manufacture. [55:10.4.1.1.2 (A)]

(B)

[GH2] containers with flaws or inclusions exceeding the lesser of 5 percent of the wall thickness or 0.12 in. (3 mm) shall not be used. [55:10.4.1.1.2 (B)]

7.3.2.4.1.3 Composite Containers. (Reserved)

7.3.2.4.2 Corrosion Protection.

[GH2] containers and underground piping shall be protected from corrosion in accordance with 7.1.9.1.7, 7.1.14, [and] 7.1.15.3 as applicable.

[55:10.4.3.1.3]

7.3.2.4.3* Outlet Connections.

7.3.2.4.3.1

Threaded [GH2] container outlet connections shall be designed with primary and secondary seals that shall be tested for functionality. [55:10.4.3.1.4.1]

7.3.2.4.3.2

The seal design shall include a method of detecting a leak in the primary seal. [55:10.4.3.1.4.2]

7.3.2.4.4 Piping Systems.

7.3.2.4.4.1

Joints in the piping system shall be installed and inspected in accordance with the requirements of ASME B31.12, Hydrogen Piping and Pipelines, or otherapproved standards. [55:10.4.3.1.5.1]

7.3.2.4.4.2

Valves, controls, safety devices, and instrumentation shall be above ground and accessible to authorized personnel. [55:10.4.3.1.5.2]

7.3.2.4.5 Location.

[GH2] containers shall be located in accordance with 7.3.2.4.5.1 through 7.3.2.4.5.6. [55:10.4.3.1.6]

7.3.2.4.5.1

Underground [GH2] containers shall not be located beneath buildings. [55:10.4.3.1.6.1]

7.3.2.4.5.2

[GH2] containers and associated equipment shall be located with respect to foundations and supports of other structures such that the loads carried by

such structures cannot be transmitted to the tank. [55:10.4.3.1.6.2]

7.3.2.4.5.3

The distance from any part of the [GH2] container to the nearest wall of a basement, pit, cellar, or lot line shall not be less than 10 ft (3.1 m).

[55:10.4.3.1.6.3]

7.3.2.4.5.4

A structure or foundation of a structure on the same property shall not be erected or constructed within 10 ft (3.1 m) of any point on the container surface,unless the footings extend to the bottom of the container or the container’s foundation. [55:10.4.3.1.6.4]

7.3.2.4.5.5

A minimum distance of 1 ft (0.3 m), shell to shell, shall be maintained between adjacent underground containers. [55:10.4.3.1.6.5]

7.3.2.4.5.6*

A minimum distance of 3 ft (0.9 m) shall be maintained between [GH2] containers and buried utilities. [55:10.4.3.1.6.6]

7.3.2.4.6 Foundations.

Underground [GH2] containers shall be set on foundations constructed in accordance with the [adopted] building code, and surrounded with not less than

6 in. (152 mm) of noncorrosive inert material. [55:10.4.3.1.7]

7.3.2.4.6.1

The concrete shall extend a minimum of 1 ft (0.3 m) horizontally beyond the footprint of the tank in all directions. [55:10.4.3.1.7.1]

7.3.2.4.7 Depth, Cover, and Fill.

7.3.2.4.7.1

Containers shall be buried such that the top of the container is covered with a minimum of 1 ft (0.3 m) of earth and with concrete a minimum of 4 in.(101 mm) thick placed over the earthen cover. [55:10.4.3.1.8]

7.3.2.4.8* Anchorage and Security.

[GH2] containers installed underground in flood hazard areas shall be anchored to prevent flotation, collapse, or lateral movement resulting from

hydrostatic loads, including the effects of buoyancy, during conditions of the design flood. [55:10.4.3.1.9]

7.3.2.4.9 Venting of Underground GH2 Containers.

Vent pipes for underground [GH2] containers shall be in accordance with 7.1.15. [55:10.4.3.1.10]

7.3.2.4.10 Overfill Protection and Prevention Systems.

An approved means or method shall be provided to prevent the overfilling of the storage containers. [55:10.4.3.1.11]

7.3.2.4.11 Physical Protection.

Piping and control equipment ancillary to underground containers that is located above ground shall be protected from physical damage in accordancewith 7.1.7.3. [55:10.4.3.1.12]

7.3.3 Bulk GH2 Systems Use.

7.3.3.1

The use of bulk GH2 systems shall be in accordance with Section 7.1.


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7.3.3.2 Good Practice Standards.

Where nationally recognized good practices or standards have been established for the processes employed, such practices and standards shall befollowed. [55:8.14.1.5.1]

7.3.4 Handling of Bulk GH2 Systems.

7.3.4.1

The handling of GH2 shall be in accordance with 7.2.4.

7.3.4.2 Cargo Transport Unloading.

7.3.4.2.1

Personnel conducting transfer operations from the bulk transport vehicle shall be trained.

7.3.4.2.2

Unloading connections on delivery equipment shall not be positioned closer to any of the exposures than distances given for the bulk GH2 compressed

gas storage system. [55:10.3.3.2]

7.3.4.2.3

During transfer of hydrogen from cargo vehicles to the bulk [GH2] compressed gas storage system, the hand or emergency brake of the vehicle shall be

set, and chock blocks shall be used to prevent the vehicle from moving. [55:10.3.3.3]

7.3.4.2.4

Cargo vehicles equipped with air-brake interlock in front of the unloading connection to protect against drive-aways shall be engaged such that theinterlock is activated. [55:10.3.3.4]

7.3.4.2.5

Mobile hydrogen supply units shall be electrically bonded to the bulk hydrogen gas storage system before hydrogen is discharged from the supply unit.[55:10.3.3.5]

7.3.4.2.6 Transfer System Depressurization.

7.3.4.2.6.1

The transfer systems shall be capable of depressurizing to facilitate disconnection. [55:10.3.3.6.1]

7.3.4.2.6.2

Bleed connections shall be connected to a hydrogen venting system in accordance with 7.1.17. [55:10.3.3.6.2]

7.3.4.2.7

Where required, check valves on delivery systems shall be in accordance with 7.1.15.1.5. [55:10.3.3.7]

7.3.4.2.8

Prohibitions on smoking or the use of open flame shall be in accordance with 7.1.26.2. [55:10.3.3.8]

7.3.4.2.9

An emergency shutoff valve shall be provided in accordance with 7.1.24. [55:10.3.3.9]


NFPA 55 deals with DOT approved vessels, as it should for bottle yards. DOT approved vessels by definition are transportable. In NFPA 2 we are dealing with transportable and stationary vessels. We need to differentiate the requirements of DOT from ASME. They are in practice different.

Additionally NFPA 55 deals with many gases stored in a limited area, one set of hazards. NFPA 2 deals with one and up to six flammable gases, not toxics, no asphyxiants, a different set of hazards. - Equipment - hazards - rules, two sets.




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7.1.4.1.1

The storage and use of metal hydride storage systems shall be in accordance with this section, 7.1.4. [55:10.2.9.1.1]


Started looking for 7.1.4. Isn’t this obvious by heading? Just say, this section.




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7.1.4.1.4* Listed or Approved Systems.

Metal hydride storage systems shall be listed or approved for the application and designed in a manner that prevents the addition or removal of the metalhydride by other than the original equipment manufacturer. [ 55: 10.2.9.1.4] hydride


Delete the last clause. It is not enforceable. We are dealing with the general public.




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Metal hydride storage system cylinders, containers, and tanks shall be inspected, tested, and requalified for service at not less than 5 5 -year intervals.[ 55: 10.2.9.1.6] or as required by local ordinance, which ever is the lesser.


Is inspection and frequency a NFPA or NBBI requirement? NFPA doesn’t inspect pressure vessels or relief valves nor set frequency. Let’s refer to local ordinance.




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7.1.4.1.7.1 System Marking.

Metal hydride storage systems shall be marked with the following:


(2) Service life indicating the last date the system can be used

(3) A unique code or serial number specific to the unit


(5) Emergency contact name, telephone number, or other contact information

(6)

(7) Limitations on refilling of containers to include rated charging pressure and capacity

[55:10.2.9.1.7.1]


Manufacturer may go out of business. Legally, the owner/operator is accountable.




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7.1.4.1.7.2 Valve Marking.

Metal hydride storage system valves shall be marked as customarily required with the following additions :


(2) Service life indicating the last date the valve can be used

(3) Metal hydride service in which the valve can be used or a product code that is traceable to this information

[55:10.2.9.1.7.2]


Valve marking is usually under the purview of ASME or MSS (same requirements). Only add to and do not repeat the requirements.




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7.1.4.1.7.3 Pressure Relief Device Marking.

Metal hydride storage system pressure relief devices shall be marked as customarily required with the following additions :


(2) Metal hydride service in which the device can be used or a product code that is traceable to this information

(3) Activation parameters to include temperature, pressure, or both

[ 55: 10.2.9.1.7.3]

(A)

(1)

The required markings for pressure relief devices that are integral components of valves used on cylinders, containers, and tanks shall be allowed to beplaced on the valve. [ 55: 10.2.9.1.7.3(A)]


Valve marking is usually under the purview of ASME or MSS (same requirements). Only add to and do not repeat the requirements. What is “A”?




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7.1.4.1.7.4 Pressure Vessel Markings.

Cylinders, containers, and tanks used in metal hydride storage systems shall be marked as customarily required with the following additions :

Manufacturer’s name

Design specification to which the vessel was manufactured

Authorized body approving the design and initial inspection and test of the vessel

Manufacturer’s original test date

Unique serial number for the vessel

:

(1) Service life identifying the last date the vessel can be used


[ 55: 10.2.9.1.7.4]


Valve marking is usually under the purview of ASME or DOT (same requirements). Only add to and do not repeat the requirements.




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Metal hydride storage systems, whether full or partially full, shall not be exposed to artificially created high temperatures exceeding 125°F (52°C) orsubambient (low) temperatures unless designed for use under the exposed conditions. [ 55: 10.2.9.1.8] temperatures exceeding the range stipulated bythe manufacturer on the system nameplate


Not enforceable. What temperature? What is “artificially created”? What is “subambient (low) temperatures”? If the gas entering it is 55 F (underground pipeline temperature) and the outside air is 70 F am I in violation?




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7.1.4.2.2 Valves.

Valves on cylinders, containers, and tanks shall remain closed closed and secured (i.e. capped or with cylinder valve cover installed) except whencontainers are connected to closed systems and ready for use. [ 55: 10.2.9.2.2] in use.


Not enforceable. Not sure this is an improvement. Maybe delete the whole item.




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Cylinders, containers, and tanks shall be designed, fabricated, tested, and marked (stamped) in accordance with regulations of DOT, Transport Canada(TC) Transportation of Dangerous Goods Regulations, or the ASME Boiler and Pressure Vessel Code, “Rules for the Construction of Unfired PressureVessels,” Section VIII . [ 55: 7.1.5.1]


WHy limit to only section VIII? Section X applies and possibly Section XII. Let the ASME Code do the directing.




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7.1.5.2.1

Defective transportable cylinders, containers, and tanks shall be returned to the supplier. [55:7.1.5.2.1]


The rules for transportable and stationary cylinders are not the same. We need to differentiate between stationary and transportable storage. A DOT3AA cylinder is an examples transportable storage.




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7.1.5.2.3 Defective stationary cylinders, containers, and tanks shall be removed from service. The owner is responsible to either repaired per localordinance or dispose of in an approved manner.


We need to differentiate between stationary and transportable storage. An ASME stamped vessel is an example of stationary storage.




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7.1.5.2.2

Suppliers shall

repairremove the transportable cylinders, containers, and tanks

, remove themfrom service

,and either repair or dispose of them in an approved manner.

[ 55: 7.1.5.2.2]


First the cylinder is removed from service, then the cylinder owner decides to repair or scrap.




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7.1.5.3 Supports.

Stationary cylinders, containers, and tanks shall be provided with engineered supports of noncombustible material on noncombustible foundations.[55:7.1.5.3]

Additional guidance on supports can be found in ASCE 7, “Minimum Design Loads for Building and Other Structures”, and ASME B31E, “Standardfor the Seismic Design and Retrofit of Above-Ground Piping Systems”


The current requirement needs support. ASCE 7, “Minimum Design Loads for Building and Other Structures”, and ASME B31E, “Standard for the Seismic Design and Retrofit of Above-Ground Piping Systems” are current references. ASCE covers structures. ASME piping systems.




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7.1.5.4 Cylinders, Containers, and Tanks Containing Residual Gas.

Stationary and transportable [ GH 2 GH2 ] cylinders, containers, and tanks containing residual product shall be treated as full except when being

examined, serviced, or refilled by a gas manufacturer, authorized cylinder requalifier, an authorized vessel repair house (“R” stamp), or distributor.[ 55: 7.1.5.4]


We need to differentiate between stationary (ASME) and transportable (DOT) storage.




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7.1.5.5.1

When required by 7.1.5.5.2, pressure relief devices shall be provided to protect containers and systems containing [GH2] from rupture in the event of

overpressure from thermal exposure. [55:7.1.5.5.1]

Pressure relief devices are to conform to either stationary or transportable storage requirements based on design and usage.


We need to differentiate between stationary and transportable storage requirements




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7.1.5.5.2

Pressure relief devices to protect transportable containers shall be designed and provided in accordance with CGA S-1.1, Pressure Relief DeviceStandards — Part 1 — Cylinders for Compressed Gases, for cylinders; CGA S-1.2, Pressure Relief Device Standards — Part 2 — Cargo and PortableTanks for Compressed Gases, for portable tanks; and CGA S-1.3, Pressure Relief Device Standards — Part 3 — Stationary Storage Containers forCompressed Gases, for stationary tanks or in accordance with applicable equivalent requirements in the country of use. [55:7.1.5.5.2]

Pressure relief devices to protect stationary storage shall be design and operated per the ASME BVPC, Section VIII.


differentiate between stationary and transportable storage.




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7.1.6.3.1

Stationary [GH2] cylinders, containers, and tanks shall be marked in accordance with NFPA 704. [ 55: 7.1.7.3.1] NFPA 704 or Hazardous Materials

Iden fica on System (HMIS) as the applica on dictates .


The intent of this PI is to suggest the TC consider differentiating between stationary and transportable storage as appropriate in Chapter 7. A CSA HGV 2 cylinder or a DOT3AA are examples of transportable storage. There are many places in section 7.1.… where this issue comes up. We wish to tee this topic up for NFPA 2, and potentially for the NFPA 2/ NFPA 55 joint discussion. This specific section is one example in section 7.1.X.. where the hydrogen application in NFPA 2 may go beyond the intent of the extract text in NFPA 55 due to the use of stationary storage systems subject to ASME rules. It is likely the best approach in these cases is to differentiate between stationary and transportable storage in NFPA 2 and remove the extract tags for NFPA 55, which may potentially not need to make similar revisions. Reference: US DoL OSHA - 29 CFR 1910.1200 Hazardous Materials Identification.



Organization: Fuel Cell and Hydrogen Energy Association

Affilliation: Fuel Cell and Hydrogen Energy Association

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7.1.6.3.1

Stationary [GH2] cylinders, containers, and tanks shall be marked in accordance with NFPA 704. [ 55: 7.1.7.3.1] or Hazardous Materials Identification

System (HMIS) as the application dictates.


There are two accepted marking systems. The second is federal regulation, US DoL OSHA - 29 CFR 1910.1200 Hazardous Materials Identification. List both as either/or.




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7.1.7.3.2

Guard posts Bollards or other means shall be provided to protect [GH2] cylinders, containers, tanks, and systems indoors and outdoors from vehicular

damage in accordance with. Section 4.14. [55:7.1.8.3.2]


A guard post is a portal through a perimeter often manned with a sentry to limit the entry of personnel. A bollard is a short vertical post. Originally it meant a post used on a ship or a quay, principally for mooring. The word now also describes a variety of structures to control or direct road traffic, such as posts arranged in a line to obstruct the passage of motor vehicles. This needs to be corrected in a number of locations in the text.




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7.1.7.4 Securing GH2 transportable Cylinders, Containers, and Tanks.

Transporable [GH2] cylinders, containers, and tanks in use or in storage shall be secured to prevent them from falling or being knocked over by corralling

them and securing them to a cart, framework, or fixed object by use of a restraint, unless otherwise permitted by 7.1.7.4.1 and 7.1.7.4.2. [55:7.1.8.4]

7.1.7.4.1

Transportable [GH2] cylinders, containers, and tanks in the process of examination, servicing, and refilling shall not be required to be secured.

[55:7.1.8.4.1]

7.1.7.4.2

At cylinder-filling plants, authorized cylinder requalifier’s facilities, and distributors’ warehouses, the nesting of cylinders shall be permitted as a means tosecure cylinders. [55:7.1.8.4.2]


We need to differentiate between stationary and transportable storage.




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7.1.9.1.2 Ledges, Platforms, and Elevators.

Transportable [GH2] cylinders, containers, and tanks shall not be placed near elevators, unprotected platform ledges, or other areas where [GH2]

cylinders, containers, or tanks could fall distances exceeding one-half the height of the cylinder, container, or tank. [55:7.1.10.4]


differentiate between stationary and transportable storage




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Transportable [GH2] cylinders, containers, and tanks, whether full or partially full, shall not be exposed to temperatures exceeding 125°F (52°C) or

subambient (low) temperatures unless designed for use under such exposure. [55:7.1.10.5]

7.1.9.1.3.1

Transportable [GH2] cylinders, containers, and tanks that have not been designed for use under elevated temperature conditions shall not be exposed to

direct sunlight outdoors where ambient temperatures exceed 125°F (52°C). The use of a weather protected structure or shaded environment for storage oruse shall be permitted as a means to protect against direct exposure to sunlight. [55:7.1.10.5.1]


There are several points here:

1. We need to differentiate between stationary and transportable storage.

2. The concern here is the inadvertent activation of the CGA S-1 valve. Stationary storage does not require S-1 valves. So this only applies to transportable storage.

3. The concern with stationary storage is the possibility of a pool fire under the storage. An appropriate approach might be to place the storage above grade, maybe a concrete slab, so that an untenable release of a liquid fuel cannot pool under the storage.

4. Consider:7.1.9.1.3 Temperature extremes7.1.9.1.3.1 Transportable storage 7.1.9.1.3.1.1 (text from 7.1.9.1.3)7.1.9.1.3.1.2 (text from 7.1.9.1.3.1)7.1.9.1.3.2 Stationary storage (pool fires)




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[GH 2 ] cylinders, containers, and tanks Stationary and transportable storage shall not be placed in areas where they are capable of being damaged by

falling objects. [55:7.1.10.6]






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7.1.9.1.5 Heating.

Stationary and transportable storage [GH2] cylinders, containers, and tanks, whether full or partially full, shall not be heated by devices that could raise the

surface temperature of the cylinder, container, or tank to above 125°F (52°C). [55:7.1.10.7]

7.1.9.1.5.1 Electrically Powered Heating Devices.

Electrical heating devices shall be in accordance with NFPA 70. [55:7.1.10.7.1]

7.1.9.1.5.2 Fail-Safe Design.

Devices designed to maintain individual [GH 2 ] cylinders, containers, or tanks at maintain Stationary and transportable storageat constant temperature

shall be designed to be fail-safe. [55:7.1.10.7.2]






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7.1.9.1.7 Exposure to Chemicals.

[GH 2 ] cylinders, containers, and tanks shall Stationary and transportable storage shall not be exposed to corrosive chemicals or fumes that could

damage cylinders, containers, tanks, or valve-protective caps. [55:7.1.10.9]






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7.1.9.1.8 Exposure to Electrical Circuits.

[GH 2 ] containers, cylinders, and tanks shall Stationary and transportable storage shall not be placed where they could become a part of an electrical

circuit. [ 55: 7.1.10.10] Storage shall be bonded and grounded per NFPA 70.

7.1.9.1.8.1*

Electrical devices mounted on [GH 2 ] piping, cylinders, containers, or tanks shall on stationary and transportable storage shall be installed, grounded, and

bonded in accordance with the methods specified in NFPA 70 (NEC). [55:7.1.10.10.1]






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Service, repair, modification, or removal of valves, pressure relief devices, or other [GH 2 ] cylinder, container, or tank appurtenances other stationary and

transportable storage appurtenances shall be performed by trained personnel and with the permission of the container owner. [55:7.1.11]






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7.1.11 Unauthorized Use.

[GH 2 ] cylinders, containers, and tanks shall Stationary and transportable storage shall not be used for any purpose other than to serve as a vessel for

containing the product for which it was designed. [55:7.1.12]


Stationary and transportable storage




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7.1.12 Cylinders, Containers, and Tanks Exposed to Fire.

[GH 2 ] cylinders, containers, and tanks exposed Stationary and transportable storage exposed to fire shall not be used or shipped while full or partially full

until they are requalified in accordance with the pressure vessel code under which they were manufactured. [55:7.1.13]






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7.1.13 Leaks, Damage, or Corrosion.

7.1.13.1* Removal From Service.

Leaking, damaged, or corroded [GH 2 ] cylinders, containers, and tanks shall corroded stationary and transportable storage shall be removed from service.

[55:7.1.14.1]

7.1.13.2 Replacement and Repair.

Leaking, damaged, or corroded [GH2] systems shall be replaced or repaired. [55:7.1.14.2]

7.1.13.3* Handling of Cylinders, Containers, and Tanks Removed from Service.

[GH 2 ] cylinders, containers, and tanks that Stationary and transportable storage that have been removed from service shall be handled in an approved

manner. [55:7.1.14.3]


We need to differentiate between stationary and transportable storage.

What does “approved manner” mean exactly? “With the tooling and to the procedures appropriate for the specific storage type design”?




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7.1.14 Surfaces.

7.1.14.1

To prevent bottom corrosion, cylinders, containers, and tanks stationary and transportable storage shall be either catholically protected, anodicallyprotected, orprotected from direct contact with soil or surfaces where water might accumulate. [55:7.1.15.1]

7.1.14.2

Surfaces shall be graded to prevent accumulation of water. [ 55: 7.1.15.2]Provision is to be made to keep storage components out of the water (and/or mud).


1. We need to differentiate between stationary and transportable storage.

2. What about outdoor and underground storage.

3. Keeping the storage out of the water may not be possible in the tidewater regions of the east and gulf coasts. Heavy rains don’t drain, they pool when the water table is only a couple of inches below grade.




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7.1.15.1* Piping Systems.

Piping, tubing, fittings, and related components shall be designed, fabricated, and installed in accordance with applicable parts of ASME B31.3, sectionsofASME B31 Code for Process Pressure Piping, and Sections 704.1.2.3, 704.1.2.4, and 704.1.2.5 of the ICC International Fuel Gas Code (IFGC). Cast- ductile, malleable or high silicon iron pipe, valves, and fittings shall not be used.

7.1.15.1.1

Prior to acceptance and initial operation, all piping installations shall be inspected and pressure tested in accordance with ASME B31 .12, Hydrogen Pipingand Pipelines Code for Pressure Piping , and ICC International Fuel Gas Code (IFGC), Section 705. [55:10.2.2.1]

7.1.15.1.2

In addition to the requirements of 7.1.15.1, brazing materials used for joints in piping and tubing systems shall have a melting point about 1000°F 840°F(538°C 450°C ). [55:10.2.2.2]

7.1.15.1.3

Underground piping system shall be in accordance with 7.1.15.3. [55:10.2.2.3]

7.1.15.1.4 Integrity.

Piping, tubing, pressure regulators, valves, and other apparatus shall be kept gastight to prevent leakage. [55:7.3.1.3.1]

7.1.15.1.5 Backflow Prevention.

Backflow prevention or check valves shall be provided where the backflow of hazardous materials could create a hazardous condition or cause theunauthorized discharge of hazardous materials. [55:7.3.1.3.2]


7.1.15.1 The designer could follow B31.1, B31.3, B31.8 or B31.12 and be safe. Let’s not limit the designer ASME doesn't.

Also ASME B31.12 cautions against the use of cast, ductile, malleable or high silicon irons [ASME B31.12 GR-2.1.4 (b)(1).]

7.1.15.1.2 Why is this arbitrary number quote? The American Welding Society defines brazing as “a group of joining processes that produce coalescence of materials by heating them to a brazing temperature and by using a filler metal having a liquidus exceeding 840°F and below the solidus of the base metals.” In actual practice, most brazing is done at temperatures from about 1100ºF to 2200F.




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Public Input No. 398-NFPA 2-2016 [ Section No. 7.1.15.1 [Excluding any Sub-Sections] ]

Piping, tubing, fittings, and related components shall be designed, fabricated, and installed in accordance with applicable parts of ASME B31. 3 12 , Codefor Process Hydrogen Piping and Pipelines , and Sections 704.1.2.3, 704.1.2.4, and 704.1.2.5 of the ICC International Fuel Gas Code (IFGC). Cast-ironpipe, valves, and fittings shall not be used.


The suggested change correlates with the testing specified in Section 7.1.15.1.1 and correlates with the ICC International Fuel Gas Code which references B31.12. B31.12 also incorporates B31.1, 2, 3, 4, 8, and 8S through a mandatory reference in Appendix II.

704.1.2 Piping systems.Piping, tubing, valves and fittings conveying gaseous hydrogen shall be designed and installed in accordance with Sections 704.1.2.1 through 704.1.2.5.1, Chapter 50 of the International Fire Code, and ASME B31.12. Cast-iron pipe, valves and fittings shall not be used.

This correlation and pointer to B31.12 may need to be looked at throughout the code.










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Underground piping can be either buried vaulted. Buried piping is physically in contact with earth at all points. Vaulted piping is run undergroundinside a vault, second pipe or hose to protect the pipe from physical in contact with earth and to aid in the detection of leaks. Piping designs withdouble containment wall are subject to the same rules as vaulted piping.

7.1.15.3.1

Underground Buried piping shall be of welded construction without valves, unwelded mechanical joints, or connections installed underground.[ 55: 7.1.17.1]

Vaulted piping shall be treated as buried piping unless leak detection monitoring is used, in which case it is to be treated as piping installed in anopen trench.

7.1.15.3.1.1


7.1.15.3.1.2

Valve boxes or enclosures installed in areas subject to vehicular traffic shall be constructed to resist uniformly distributed and concentrated live loads inaccordance with the [adopted] building code for areas designated as vehicular driveways and yards, subject to trucking. [55:7.1.17.1.1.1]

7.1.15.3.1.3*

Piping installed in trench systems located below grade where the trench is open to above an open trench shall not be considered to be underground.[ 55: 7.1.17.1.2] underground piping if the ventilation is equivalent to above ground piping


7.1.15.3.2.1


7.1.15.3.2.2


7.1.15.3.3


7.1.15.3.4


7.1.15.3.5


7.1.15.3.6

In paved areas where a minimum 4 in. (100 mm) of reinforced concrete is used, backfill between the pipe and the concrete shall be permitted to be reducedto 4 in. (100 mm) minimum. [30:27.6.5.4]

7.1.15.3.7


7.1.15.3.8


7.1.15.3.9


7.1.15.3.10


7.1.15.3.11



7.1.15.3 There are different rules for vaulted versus buried piping? Where are they?7.1.15.3.1 This tweak should clarify.7.1.15.3.1.3 How open? Periodic vault vents or entirely covered with deck grating?




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Underground piping can be either buried vaulted. Buried piping is physically in contact with earth at all points. Vaulted piping is run undergroundinside a vault, second pipe or hose to protect the pipe from physical in contact with earth and to aid in the detection of leaks. Piping designs withdouble containment wall are subject to the same rules as vaulted piping.

7.1.15.3.1

Underground Buried piping shall be of welded construction without valves, unwelded mechanical joints, or connections installed underground.[ 55: 7.1.17.1]

7.1.15.3.1.1


7.1.15.3.1.2

Valve boxes or enclosures installed in areas subject to vehicular traffic shall be constructed to resist uniformly distributed and concentrated live loads inaccordance with the [adopted] building code for areas designated as vehicular driveways and yards, subject to trucking. [ 55: 7.1.17.1.1.1]

Vaulted piping shall be treated as buried piping unless leak detection monitoring is used, in which case it is to be treated as piping installed in anopen trench.

7.1.15.3.1.3

Piping installed in an open trench shall not be considered underground piping if the ventilation is equivalent to above ground piping .

7.1.15.3.1.3 4 *

Piping installed in trench systems located below grade where the trench is open to above an open trench shall not be considered to be underground.[ 55: 7.1.17.1.2] underground piping if the ventilation is equivalent to above ground piping .


7.1.15.3.2.1


7.1.15.3.2.2


7.1.15.3.3


7.1.15.3.4


7.1.15.3.5


7.1.15.3.6

In paved areas where a minimum 4 in. (100 mm) of reinforced concrete is used, backfill between the pipe and the concrete shall be permitted to be reducedto 4 in. (100 mm) minimum. [30:27.6.5.4]

7.1.15.3.7


7.1.15.3.8


7.1.15.3.9


7.1.15.3.10


7.1.15.3.11



The intent of this PI is to clarify requirements for vaulted versus buried piping. This PI provides some clarification; however further work is needed.

7.1.15.3 There are different rules for vaulted versus buried piping. (Where are they?) Recommend clarifying language and pointing to the appropriate section.

7.1.15.3.1 Clarification.

7.1.15.3.1.3* Clarification needed: How open? Periodic vault vents or entirely covered with deck grating?



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Affilliation: FCHEA

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7.1.16 Valves Valve handles and actuators .

7.1.16.1

Valves utilized on [GH 2 ] systems shall be designed for the gas or gases and pressure intended and shall be accessible. [ 55: 7. 3. 1. 4.1]

7.1.16.2

Valve handles or operators for required shutoff 16.2.1 Valves not accessible to the general public with handles or actuators required to close the valvesshall not be removed or otherwise altered to prevent access. [ 55:

7.

3.

1.

4

16 .2

]

Valves accessible to the general public shall be tamper resistant


1. Access by the general public needs to be addressed. The AHJ has found with other fuel gases that historically tampering is a greater threat so they required standardized valves and the first responders carry the tools to close the valve.

2. An operator is a person, an actuator is a device. A handle is a manual actuator.




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7.1.17.1

Venting from the relief vents from the hydrogen supply piping serving listed fuel cell power systems shall be permitted to be discharged into an enclosureintegral to the fuel cell system where the concentration of hydrogen is diluted below 25 percent of the lower flammable limit (LFL) at the outlet of theenclosure. [ 55: 10.2.3.1]


Delete this redundant requirement. All fuel cell requirements are in NFPA 853, refer to chapter 12. This specific topic is covered in NFPA 853 Chapter 7.




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7.1.17.2

Process versus relief venting

7.1.17.2.1 The hydrogen supply piping system shall be designed to isolate the source of hydrogen from a process or exhaust vent in the eventof loss of dilution ventilation or power. [ 55: 10.2.3.1.1]

7.1.17.2.2 The hydrogen supply piping system shall be designed to not isolate or obstruct the source of hydrogen from a relief vent in the eventof loss of dilution ventilation or power. [ 55: 10.2.3.1.1]


A relief vent is the exit path from a relief valve. Isolation downstream of the relief valve is against code and a really bad idea.

Differentiating between safety relief valve vents and process (or exhaust) vent would be wise.




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7.1.17.3.1

Venting of [GH 2 ] shall be directed to an approved location. [ 55: 7.3.1.5.1] and other potential sources of combustible gas shall be vented the outside of

the building, terminating at least 4.6 m (15 ft) from air intakes, windows, doors, or other building openings.

7.1.17.3.2

The termination point for piped vent systems serving cylinders, containers, tanks, and gas systems used for the purpose of operational or emergencyventing shall be in accordance with Section 6.16 . [ 55: 7.3.1.5.2] with CGA G-5.5, Hydrogen Vent Systems


Not actionable. What does “directed to an approved location” mean? Who approves?

Not user friendly. Section 6.16 sends you to CGA G-5.5, Hydrogen Vent Systems. Just call out the reference.




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7.1.18 Cathodic Protection.

Where required, cathodic protection shall be in accordance with this section, section 7.1.18. [55:7.1.6]

7.1.18.1 Operation.


7.1.18.2 Inspection.

Container systems equipped with cathodic protection shall be inspected for [proper] operation by a cathodic protection tester. The frequency of inspectionshall be determined by the designer of the cathodic protection system. [55:7.1.6.2]

7.1.18.2.1



Systems equipped with impressed current cathodic protection systems shall be inspected in accordance with the requirements of the design and 7.1.18.2.[55:7.1.6.3]

7.1.18.3.1

The design limits of the cathodic protection system shall be available to the AHJ upon request. [55:7.1.6.3.1]

7.1.18.3.2




[55:7.1.6.3.2]

7.1.18.4 Corrosion Expert.


7.1.18.4.1



This statement says to leave 7.1.18 to go to 7.1.18. It is circular (itself)




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Where required, cathodic protection shall be in accordance with 7.1.18 . [this section]. [55:7.1.6]


The text refers to itself.




Affilliation: FCHEA

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7.1.19 Transfer.

Transfer of [GH2] between cylinders, containers, and tanks cstationary and transportable storages shall be performed by qualified personnel using

equipment and operating procedures in accordance with CGA P-1, Safe Handling of Compressed Gases in Containers. [ 55: 7.3.1.9] Transfer of [GH2]between stationary and transportation storage is discussed in chapter 10 of this document


We need to differentiate between stationary and transportable storage and embellish a bit.




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7.1.19 Transfer.

Transfer of [GH2] between cylinders, containers, and tanks stationary and transportable storage shall be performed by qualified personnel using

equipment and operating procedures in accordance with CGA P-1, Safe Handling of Compressed Gases in Containers. [55:7.3.1.9]

7.1.19.1

Transfer of [GH2] between stationary and transportation storage is discussed in chapter 10 of this document.


Submitted correlating PI to NFPA 55 this cycle (81 NFPA 55: 2016). Intent is to differentiate between stationary and transportable storage as requirements differ. For this document, PI also adds a pointer for requirements for transferring between stationary and transportable storage.




Affilliation: FCHEA

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7.1.20.3

Control circuits that automatically shut downWhen an automatic shutdown control shuts down a system. The system shall remain down until manually activated or reset

after a safe shutdown is performed. [ 55: 10.2.5.3]by personnel authorized by the owner/operator after determination of the cause of the shut down and the determination that the system is safe torestart.


Not a sentence. I think this is what was (or should have been) intended.




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7.1.21.1 Valves.

(A)

Valves shall be installed such that each compressor is able to be isolated for maintenance. [55:10.2.5.4.1.1]

(B)

The discharge line shall be equipped with a check valve to prevent the backflow of gas from high-pressure sources located downstream of the compressor.[55:10.2.5.4.1.2]


We need a requirement, not a selection of method and hardware. Besides “check valves don’t check”…




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7.1.21.2 Foundations.

(A)

Foundations used for supporting equipment shall be designed and constructed to prevent frost heaving. [ 55: 10.2.5.5.1]

(B)

The structural aspects of such foundations shall be designed and constructed in accordance with the provisions of NFPA 5000, ICC IBC or as supersededby the [adopted] building code . [ 55: 10.2.5.5.2]


1. Paragraph A is redundant with paragraph B. 2. Why isn’t NFPA referencing NFPA codes?




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7.1.21.3 Emergency Shutdown.

When an emergency shutdown system is required, activation of the emergency shutdown system shall shut down operation of all compressors serving asingle gas installation. [55:10.2.5.6]


What is the difference between an automatic shutdown and an emergency shutdown? To me, an automatic shutdown occurs when a sensor detects and anomaly an initiates a standard controlled shutdown protecting the hardware from further potential damage.

An emergency shutdown is initiated either automatically or manually in response to an unsafe condition or event. An emergency shutdown does not protect hardware. It is used to protect personnel and the general public.

In each case, the system should include a LOR (lock out relay) which requires the fault to be corrected and the system inspected by authorized (trained) personnel prior to locally resetting the lock out.




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7.1.21.4 Relief Valves. Over pressure protection

(A)

Each compressor shall be provided with a vent or relief device that will means ro prevent overpressurizing of the compressor under normal or and upsetconditions. [ 55: 10.2.5.7.1]

(B)

Pressure relief devices used to serve pumps or compression equipment shall be connected to a vent pipe system in accordance with 7.1.17.[55:10.2.5.7.2]


1. State what the requirement is.

2. We need a requirement, not a selection of method and hardware. Besides relief valves are not the only solution and avoidance of a release is preferable.




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7.1.21.5 Pressure Monitoring.

The pressure on the compressor discharge shall be monitored by a control system. [55:10.2.5.8]

(A)

Discharge pressures in excess of the equipment design maximum operating pressures shall cause the compressor to shut down. [55:10.2.5.8.1]


Better to shut down before allowing a process release.




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Move HEE to Chapter 6

Move 7.1.23 to Chapter-6 in a new section between 6.19 Exhausted enclosures and 6.20 Source valve.


Substantiation Statement: HEEs are General Requirements applicable to LH2 pumping systems as well as compressors and cryo-compressors. H2 Station products (HEEs) exist today that and can connect to a compressed hydrogen supply or liquid hydrogen supply system. Such systems may perform heat exchange of the dispensed hydrogen at high pressure with cryogenic hydrogen at low pressure, reducing energy waste for precooling. These \ heat exchange mechanisms and integrated system packaging benefit the need for compact foot print support the hydrogen economy.

Likewise LH2-pumps, such as those installed at Livermore National Laboratory, are prefabricated inside an HEE, according to risk assessment, safety integrity levels, hazop, and layer of protection analysis.

NFPA 2 should extend the HEEs requirement to support LH2 equipment in order to safely commercialize advanced hydrogen technologies provide guidance to the AHJ.

NFPA-2 Technical Committee Sub-group Comments: Good to go into NFPA 2.





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7.1.23 Hydrogen Equipment Enclosures.

7.1.23.1

Hydrogen equipment enclosures (HEE) shall be in accordance with 7.1.23 when the total quantity of hydrogen stored in the enclosure or piped into the

enclosure exceeds 1000 scf (28.3 Nm 3 ) or the enclosure contains hydrogen processing or generating equipment.

7.1.23.1.1

Subsection 7.1.23 does not apply to:

(1) Gas cabinets in accordance with Section 6.18

(2) Exhausted enclosures in accordance with 6.19

(3) Enclosures integral to fuel cell systems that are listed or approved in accordance with Chapter 12

(4) Enclosures integral to hydrogen generators that are listed or approved in accordance with Chapter 13

7.1.23.1.2



7.1.23.2.1

HEE grounding and equipment bonding within the enclosure shall comply with all of the following:

(1) The HEE structure shall be grounded in accordance with NFPA 70 .

(2) All conductive parts of the enclosure shall be grounded or bonded.

(3) Hydrogen piping and equipment shall be bonded to the HEE structure to prevent static discharge.

7.1.23.3

GH 2 shall not be vented within the HEE or to compartments within a HEE.

7.1.23.3.1

Vent pipes shall be in accordance with Section 7.1.17.3 .

7.1.23.3.2

Pressure relief devices and valves discharging to the atmosphere shall be vented in accordance with 7.1.5.5.5 .

7.1.23.4

A HEE that can be entered and contains or is connected to a source of GH 2 shall be evaluated for the potential of an oxygen-deficient atmosphere during

normal or off-normal conditions.

7.1.23.4.1


7.1.23.4.1.1


7.1.23.4.1.2

If a GH 2 detection system is provided in accordance with Section 6.12 , oxygen detectors are not required.

7.1.23.5 Security.

7.1.23.5.1

Exterior access doors for a HEE shall be secured against unauthorized entry.

7.1.23.5.1.1

Exterior access doors shall not be required to be secured if a secured perimeter fence or wall is provided to prevent unauthorized entry.

7.1.23.5.2

Locks or latches shall not require the use of a key, a tool, or special knowledge or effort for the operation from the egress side.

7.1.23.6 *

Means of egress for a HEE shall be in accordance with 7.1.23.6.1 , unless the HEE cannot be entered.

7.1.23.6.1

Not fewer than two means of egress shall be provided from each equipment enclosure or equipment compartment, unless all of the following criteria aremet:

(1) Undivided HEE or equipment compartments do not exceed 200 ft 2 (18.6 m 2 ), and

(2) HEE or equipment compartments have a travel distance to the room or compartment exit door(s) not exceeding 15 ft (4.6 m).


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7.1.23.6.1.1

The means of egress shall have:

(1) A minimum of 28 in. (710 mm) clear width, and

(2) A minimum headroom of not less than 6 ft, 8 in. (2030 mm) along the entire designated means of egress path

7.1.23.7

Hydrogen piping and equipment shall be isolated, depressurized, and made safe prior to replacement.

7.1.23.8


7.1.23.9 Isolation of GH 2 Storage.

7.1.23.9.1

Where required by Table 7.1.23.9.1 , a means for isolation of GH 2 storage shall be provided in accordance with 7.1.23.9 .


HEE or a compartment in a HEE contains: GH 2 storage GH 2 storage Hydrogen generation, compression and/or processing equipment Support

equipment room (in an HEE) Enclosure Volume: <200 ft 3 ≥200 ft 3 Not limited Not limited Contains or is connected to a source ofhydrogen: Yes Yes Yes No Automatic isolation from GH 2 storage Not required Not required Required Not applicable Ventilation Natural or

mechanical Natural for 3-walls HEE/mechanical for 4-walls HEE Mechanical No additional requirement Storage compartment separation Not applicable Notapplicable Required Required Electrical equipment Per NFPA 70 , Chapter 5 Per NFPA 70 , Chapter 5 Per NFPA 70 ,Chapter 5 Unclassified Bonding/grounding Required Required Required Per NFPA 70 Explosion control Not required Required Required Notrequired Detection Loss of ventilation* GH 2 , Loss of ventilation* GH 2 , Fire and Loss of ventilation GH 2 if necessary to meet the requirements of

7.1.23.10.3.1


7.1.23.9.2 *

GH 2 storage shall be equipped with automatic emergency shutoff valves to isolate the source of hydrogen from the delivery piping system.

7.1.23.9.3


7.1.23.9.4

Automatic emergency shutoff valves shall operate on GH 2 detection alarms, fire alarms, and emergency shutdown system activations.

7.1.23.9.5


7.1.23.9.6

GH 2 generation and compression equipment within a HEE which supplies hydrogen to storage containers shall be equipped with either an external



7.1.23.10.1

Where required by Table 7.1.23.9.1 , ventilation shall be provided in accordance with 7.1.23.10 .

7.1.23.10.2

A HEE and compartments within a HEE that contain GH 2 storage, equipment, or piping shall be provided with ventilation in accordance with 7.3.2.2.2.2 .

7.1.23.10.3

Natural ventilation openings and air intakes for mechanical ventilation systems shall be separated from non-bulk sources of GH 2 in accordance with

7.2.2.3.2.2 and from bulk sources of GH 2 in accordance with 7.3.2.3.1.1 .

7.1.23.10.3.1

Air intakes and ventilation openings shall not be required to meet the requirements of 7.1.23.10.3 where the compartment is provided with GH 2 detection

in accordance with 7.1.23.14 , which deactivates power to all electrical equipment within the enclosure upon detection of 25 percent of the LFL.

7.1.23.11 Storage Area Separation.

7.1.23.11.1

Where required by Table 7.1.23.9.1 , storage area separation shall be provided in accordance with 7.1.23.11 .

7.1.23.11.2

Fuel cell equipment, compressors, hydrogen generators, electrical distribution equipment, and similar appliances shall be separated from GH 2 storage

areas within the HEE by a one-hour fire rated barrier that is also capable of preventing gas transmission.


7.1.23.12.1

All electrical equipment in a HEE that has GH 2 piping, storage, generation, or processing equipment shall be in accordance with Chapter 5 of NFPA 70 .

7.1.23.12.2

Electrical equipment within 15 ft (4.6 m) of any natural ventilation opening or required exhaust discharge of a HEE shall comply with the requirements ofChapter 5 of NFPA 70 .

7.1.23.13 Emergency Shutdown System.

7.1.23.13.1

An emergency shutdown system (ESS) shall be provided for the HEE.


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7.1.23.13.1.1

The ESS shall operate on GH 2 detection alarms, fire alarms, and loss of ventilation alarms, where these are required by Table 7.1.23.9.1 .

7.1.23.13.1.2

The ESS shall operate upon activation of a manual emergency shutdown device (ESD).

7.1.23.13.1.3

The ESS shall operate across all interconnected HEE at a common site.

7.1.23.13.1.4

Where activated, the ESS shall de-energize unclassified electrical equipment inside compartments containing hydrogen or other flammable gases andclose all automatic shutoff control valves on piping into and from interconnected HEE and HEE compartments containing hydrogen equipment.

7.1.23.13.1.5

A manual ESD shall be located on the exterior of each HEE that is interconnected to the hydrogen system.

(A)

The ESD shall be identified by a sign located at the exterior of the equipment enclosure.

7.1.23.13.1.6

A remote emergency shutdown shall be located not less than 25 ft (7.6 m) and not more than 100 ft (30 m) from HEE equipped with individual ESDs.

7.1.23.14 Detection.

7.1.23.14.1

Where required by Table 7.1.23.9.1 , GH 2 detection, fire detection, and loss of ventilation detection shall be provided in accordance with 7.1.23.14 .

7.1.23.14.2

GH 2 detection shall be provided in accordance with Section 6.12 .

7.1.23.14.2.1

Detection of hydrogen above 25 percent of the LFL shall result in activation of the ESS, and shall be indicated by a visible notification device mounted onthe exterior of the HEE.

7.1.23.14.3

Heat detectors or flame detectors shall be provided and installed in accordance in NFPA 72 .

7.1.23.14.4


7.1.23.14.4.1

The device shall activate the ESS when airflow drops below 75 percent of the required flow.

7.1.23.15 Explosion Control.

7.1.23.15.1

Where required by Table 7.1.23.9.1 , explosion control shall be provided in accordance with Section 6.9 .

7.1.23.15.1.1

Explosion vents, where used, shall not discharge into adjacent HEE compartments.


This is a placeholder public input requesting that the Technical Committee perform a proper risk analysis on the HEE requirements and modify them during the public comment period. A proper risk analysis was not performed when these HEE requirements were created. They were also significantly modified during the public comment hearing without proper review. I am NOT requesting to delete this section.





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7.1.23.1.2


7.1.23.1.x

When the exterior enclosure walls carry a fire resistance rating, the fire rating shall be specified by the HEE manufacturer.


This is a new requirement. The manufacturer may take credit for reduction of setback distances by the use of containment, gas detection, ESD system, ventilation, and fire resistance as approved by the AHJ.



Organization: Boyd Hydrogen Llc

Affilliation: BoydH2 on behalf of Linde, LLC

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7.1.23.1.2*

HEE structural members shall be constructed of noncombustible materials.

A.7.1.23.1.2

HEE structures such as ISO containers and custom enclosures are typically framed using metal. Converted ISO containers may have a wooden floor thatis covered with metal, and may have interior wall and ceiling insulation protected by fire rated material.


Language is too broad and limiting. Original intent of clause is to preclude all wood construction or garden shed as an HEE. Instead, allow for industry practice of constructing HEE with noncombustible structural members and using fire retardant or fire rated interior insulating materials.

Today, industry constructs HEE using metal containers or enclosures that also use 1/2 hour gypsum and insulation, or 1/2 hour fire retardant coated laminated insulation board, to add thermal or sonic insulation for the equipment within. Listed water electrolyzers placed in an insulated ISO container HEE for environmental protection are a common example; compressors in an HEE with sound damping materials are another.

In the case where rated and listed water electrolyzers are placed in HEE for environmental protection,


Submitter Full Name: Lawrence Moulthrop

Organization: Proton Energy Systems Inc

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7.1.23.3 Hydrogen Vent Systems

7.1.23.3.1

GH2 shall not be vented within the HEE or to compartments within a HEE.

7.1.23.3.1 2

Vent pipes shall be in accordance with Section 7.1.17.3.

7.1.23.3.2 3

Pressure relief devices and valves discharging to the atmosphere shall be vented in accordance with 7.1.5.5.5.


This section is all about Hydrogen Vent Systems. for editorial clarity create a section title and move the first requirement under the title




Affilliation: BoydH2

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7.1.23.4

A HEE that can be entered and contains or is connected to a source of GH2 shall be evaluated for to determine if it is to be considered a confined space

(i.e has the potential of an oxygen-deficient atmosphere) during normal or off-normal conditions.

7.1.23.4.1

Where the potential exists for an oxygen-deficient atmosphere, detection and notification appliances shall be provided to warn personnel of an oxygen-deficient atmosphere

Confined spaces shall be identified and marked as such .

7.1.23.4.1.1


7.1.23.4.1.2

If a GH 2 detection system is provided in accordance with Section 6.12 , oxygen detectors are not required.


OSHA requirement, OSHA terms.

Low H2 doesn't mean low N2. OSHA requires O2 measurements




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7.1.23.4

A HEE that can be entered and contains or is connected to a source of GH2 shall be evaluated for to determine if it is to be considered a confined space

(i.e has the potential of an oxygen-deficient atmosphere) during normal or off-normal conditions.

7.1.23.4.1

Where the potential exists for an oxygen-deficient atmosphere, detection and notification appliances shall be provided to warn personnel of an oxygen-deficient atmosphere

Confined spaces shall be identified and marked as such .

7.1.23.4.1.1


7.1.23.4.1.2



OSHA requirement, OSHA terms.




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7.1.23.4.1 Alarms

7.1.23.4.1.1


7.1.23.4.1.1 2


7.1.23.4.1.2 3



This section is all about Alarms. for editorial clarity, create section title and move first requirement "down"





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7.1.23.7

Hydrogen piping and equipment shall be isolated, depressurized, and made safe prior to replacement. Means to do so shall be provided.


The HEE sub-group discussed this at length and wanted to add a prescriptive statement to support the operational direction of the existing section/language.





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7.1.23.7

Hydrogen piping and equipment shall be isolated, depressurized, and made safe prior to replacement, maintenance or service . Means to do so shall beprovided.


The HEE sub-group discussed adding the words "maintenance or service" to include other possible industry locations where work may take place. Then move this to the general section of HEE under 7.1.23 for clarity and organization.





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7.1.23.8 1.3



this is a general requirement and should be moved up to the general requirements in section 7.23.1





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7.1.23.9 Isolation of GH2 Storage.

7.1.23.9.1









Yes Yes Yes No










ventilation


requirements of 7.1.23.10.3.1


7.1.23.9.2*

GH2 storage shall be equipped with automatic emergency shutoff valves to isolate the source of hydrogen from the delivery dispenser supply piping

system.

7.1.23.9.3

Automatic emergency shutoff valves shall be located within the same compartment as the in close proximity to the hydrogen storage.

7.1.23.9.4


7.1.23.9.5


7.1.23.9.6

GH 2 generation and compression equipment within a HEE which supplies hydrogen to storage containers shall be equipped with either an external

automatic emergency shutoff valve or non-return valve on the exit piping outside the enclosure or compartment fail in the closed position .


7.1.23.9.2 Delivery to or from storage? I believe you are referring to the dispenser supply7.1.23.9.3 Why can’t the valve be outside the HEE, negating the need for hardware for classified areas? A couple of feet of pipe and a gas barrier vs C1D1 or C1D2 hardware?7.1.23.9.5 Don’t have to get into valve actuation: electrical, pneumatic, hydraulic, mechanical. Just state the requirement.




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7.1.23.9 Isolation of GH 2 Storage Protection Features for Hydrogen Equipment Enclosures .

7.1.23.9.1









Yes Yes Yes No










ventilation




7.1.23.9.2*

GH2 storage shall be equipped with automatic emergency shutoff valves to isolate the source of hydrogen from the delivery piping system.

7.1.23.9.3


7.1.23.9.4


7.1.23.9.5


7.1.23.9.6

GH2 generation and compression equipment within a HEE which supplies hydrogen to storage containers shall be equipped with either an external



The section was titled incorrectly in the 2016 version of NFPA 2. This section address all protection features, not just isolation.


Submitter Full Name: Nick Barilo

Organization: Pacific Northwest National Lab

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7.1.23.9.1




GH 2 storage GH 2 storageHydrogen generation,compression and/or



Enclosure Volume: <200 ft 3 ≥200 ft 3 Not limited Not limited


Yes Yes Yes No

Automatic isolation from GH 2storage


Ventilation Natural or mechanical Natural

for 3-walls HEE/mechanical for 4-walls HEE

or mechanical Mechanical No additionalrequirement

Storage compartmentseparation

Not applicable Not applicable Required Required

Electrical equipment Per NFPA 70 ,Chapter 5

Per NFPA 70 ,Chapter 5

Per NFPA 70 , Chapter 5 Unclassified



Detection Loss of ventilation* GH 2 , Loss of

ventilation*

GH 2 , Fire and Loss of

ventilation

GH 2 if necessary to meet the requirements of

7.1.23.10.3.1



The Terra inputs to table 7.1.23.9.1 look scrambled after my changes, the NFPA-2 Technical Committee HEE sub-group discussed and wanted to remove the specific type of ventilation requirements for 3 or 4 walls, and leave the option open to natural or mechanical and allow the designers to determine and demonstrate based on a safety plan or risk assessment of the design.





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7.1.23.9.1









Yes Yes Yes No



Ventilation Natural or mechanical Natural for 3-wallsHEE/mechanical for 4-wallsHEE or mechnanical







ventilation





The safety plan resulting from the risk review will dictate if natural or mechanical ventilation is needed for a “storage” compartment. Typically the most probable leak points are at the compressor system and control system valves which are not part of “storage” areas. The existing requirement for mechanical ventilation is too prosctriptive.




Affilliation: BoydH2 on behalf of Linde, LLC and in support of the NFPA 2 TG on HEE

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Public Input No. 361-NFPA 2-2016 [ Sections 7.1.23.10.2, 7.1.23.10.3 ]

Sections 7.1.23.10.2, 7.1.23.10.3

7.1.23.10.2

A HEE and compartments within a HEE that contain GH2 storage, equipment, or piping shall be provided with ventilation in accordance with 7 Section

6 . 3.2.2.2.2.

7.1.23.10.3

Natural ventilation openings and air intakes for mechanical ventilation systems shall be separated from non-bulk sources of GH 2 in accordance with

7.2.2.3.2.2 and from bulk sources of GH 2 in accordance with 7.3.2.3.1.1 .

7.1.23.10.3.1

Air intakes and ventilation openings shall not be required to meet the requirements of 7.1.23.10.3 where the compartment is provided with GH 2 detection

in accordance with 7.1.23.14 , which deactivates power to all electrical equipment within the enclosure upon detection of 25 percent of the LFL.

17 .







Public Input No. 358-NFPA 2-2016 [Sections 6.17.1, 6.17.2] Part of Package





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7.1.23.10.3.1

Air intakes and ventilation openings shall not be required to meet the requirements of 7.1.23.10.3 where the compartment is provided with GH2 detection in

accordance with 7.1.23.14, which deactivates power to all electrical equipment initiates the ESS Emergency Station Shut-down system for the equipmentwithin the enclosure upon detection of 25 percent greater than 50 percent of the LFL.


Substantiation Statement: Not all electrical equipment should be shut off. Not the sensors, not the control system, only sparking or high voltage electrical equipment and active the ESS system systems. The way the current requirement reads is potentially unsafe, sensors should be able to keep detecting and all rated electrical systems continue to function.

Detection of 25% may stop equipment normally (“Soft shutdown”) or may trigger alterative action such as increased ventilation rates. the published LFL is 4% H2 in air, Let’s allow equipment vendors to take alternative action or mitigation steps at 1% H2 in air (25% of LFL) and raise the level requiring automatic shutdown to 2% H2 in air (50% of LFL). The HEE vendor should be able to select a lower activation level if suggested by risk assessment or other criteria.

Comments: 7.1.23.13.1.4 page 2-37 enclosure references.

The HEE sub-group had much discussion on this point, the general consensus was to allow some rated equipment to continue to operate during the soft shut-down phase to provide measurements or telemetry to further assess the conditions. Should be thoroughly discussed at the Technical Committee.





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7.1.23.11.3

Change title 7.2.23.11 Storage Area Separation, to Storage Area. Add section after 7.1.23.11.2 as follows:

Composite storage tubes with combustible carbon fibre reinforcing for structural integrity shall be protected from potential impinging jet fires from potentialleaking components in the HEE by a 1-hour fire rated/resistant construction.


Substantiation Statement:7.1.23.11.2: Not all electrical equipment should be shut off. Not the sensors, not the control system, only unclassified electricals7.1.23.11.3: This is a necessary addition as it addresses the key issues regarding the use of composite cylinders: keep potential jet fires from impinging on the carbon fiber tubes

There were some late comments from sub-group members that did not make it to discussion during the phone meeting of 23 June'16, we believe this should go to the TC for general discussion. This also aligns with the input to revise 7.1.23.10.3 to modify the electrical equipment shut-down during activation of the emergency shut-down system.

A revision to section 7.1.23.11.4 was withdrawn from the sub-group input.




Affilliation: NFPA-2 Technical Committee, HEE sub-group input.

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7.1.23.11 Storage Area Separation Areas .

7.1.23.11.1

Where required by Table 7.1.23.9.1, storage area separation shall be provided in accordance with 7.1.23.11.

7.1.23.11.2

Fuel cell equipment, compressors, Unclassified electrial equpment, fuel cell power supplies, hydrogen generators, electrical distribution equipment, andsimilar appliances shall be separated from GH2 storage areas within the HEE by a one-hour fire rated barrier that is also capable of preventing gas

transmission.

7.1.23.11.3

Composite storage tubes with combustible carbon fiber reinforcing for structural integrity shall be protected from potential impinging jet fires from potentialleaking components in the HEE by a 1 hour fire resistant construction.


Revise section title to address all storage area requirements

7.1.23.11.2: Not all electrical equipment should be shut off. Not the sensors, not the control system, only unclassified electricals7.1.23.11.3: This is a necessary addition as it addresses the key issues regarding the use of composite cylinders: keep potential jet fires from impinging on the carbon fiber tubes




Affilliation: BoydH2 on behalf of Linde and the NFPA 2 TG on HEE to clarify the intent of proposed changes

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7.1.23.11.2

Fuel cell equipment, compressors, hydrogen hydrogen generators, electrical distribution equipment, and similar appliances shall be separated from GH2storage areas within the HEE by a one-hour fire rated barrier that is also capable of preventing gas transmission.


Substantiation Statement: GH2 Storage areas must be protected from fire. Within an HEE, compressors, fuel cell equipment, hydrogen generators, electrical distribution, and similar appliances are sources of flame jets, oil/lubricant fires/fuel, rotating machinery, and high voltage equipment that should be separated from GH2 Storage with appropriately designed fire barriers. GH2 Cylinders whether Types I, II, III, or IV are mechanically impacted by the high temperature of a flame. Likewise, GH2 storage areas can be the source of jet fires that must also be prevented from impacting the other equipment in the HEE. Gas transmission from either the GH2 storage area into equipment area, or vice versa, should not be considered a hazard as the HEE is required to have ventilation systems, detection, and shutoff to manage the transmission of gasses, appropriate to that HEE, as indicated in Table 7.1.23.9.1. Additionally, sources of ignition are adequately managed by the electrical area classification and rated electrical equipment inside the HEE.

Sub-group Comments: This needs work, need two requirements one for gas electrical areas and the other for mechanical compartments. The group thinks this needs further discussion but wanted to get this in front of the TC.





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7.1.23.12.1

All electrical equipment in a HEE that has

GH 2

GH2 piping, storage, generation, or processing equipment shall be selected and installed in accordance with

Chapter 5 of NFPA 70

Articles 500 through 505 of NFPA 70 .

7.1.23.12.2

Electrical equipment within

15 ft

15 ft (4.

6 m

6 m ) of any natural ventilation opening or required exhaust discharge of a HEE shall

comply

be selected and installed in accordance with the requirements of

Chapter 5 of NFPA 70

Articles 500 through 505 of NFPA 70 .


NFPA 70 Chapter 5 is too broad a reference. It covers hospitals, theaters, recreational vehicles, etc. We should be discussing classified areas.




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7.1.23.13.1.6

A remote emergency shutdown shall be located based on the accessibility to the general public and local ordinance.

7.1.23.13.1.6.1 For locations not accessible to the general public a remote emergency shutdown shall be located not less than

25 ft

25 ft (7.

6 m

6 m ) and not more than

100 ft

100 ft (

30 m

30 m ) from HEE equipped with individual ESDs.

7.1.23.13.1.6.2 For locations accessible to the general public, the placement of an ESD shall conform to the local regulations for ESDs atpetroleum fueling stations.


Need to deal with the differences between accessible and non-accessible to the general public. Is a false activation is more like and dangerous than no activation? What are the local ordinances for petroleum fueling stations? Might as well use the rules the AHJ will impose.




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7.1.23.14.2.1

Detection of hydrogen above 25 percent at greater than 50 percent of the LFL shall result in activation of the ESS, and shall be indicated by a visiblenotification device mounted on the exterior of the HEE.


HEE sub-group input, this aligns with input to 7.1.23.10.3.1 for greater than 50% LFL activation. The sub-group also wanted to make sure that the TC were comfortable with the substantiation that included sensor technology issues and false positives. This should have more discussion in the TC.





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7.1.23.14.3

Heat detectors or flame detectors shall be provided and installed in accordance in Fire detection shall be provided. The type of detection shall be asdetermined by a risk assessment. Fire detection shall be in accordance with NFPA 72.


Substantiation Statement: Need to link this to the Table 7.1.23.9.1 requirement for fire detection, i.e. clarify that heat detection is adequate fire detection.NFPA 72 is for buildings, occupancies. Consider deleting the reference to NFPA-72 and only referencing NFPA-79 and best industrial practice. We need to find better words to get into more industrial appliance manufacturing practices and get away from the building code requirement based NFPA-72.

The HEE sub-group discussed this at length and wanted to allow the designer to use a risk assessment to determine the type of fire detection that will meet the needs of the prescriptive requirement to have fire detection. I left the NFPA-79 reference in the statement, the was some discussion this did not apply. For TC discussion.





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7.1.23.14.4


7.1.23.14.4.1

The device shall activate the ESS when airflow drops below 75 percent at 75 percent of the required flow. ventilation performance threshlod. Add annexstatement, the performance threshold and means to monitor the ventilation system should be determined by the system designer through a riskassessment.


HEE sub-group Substantiation Statement:Airflow sensors are too proscriptive and functionally problematic in practice. Motor control feedback to the PLC and motor overload controls are an effective way to determine if ventilation systems are functioning. Loss of Ventilation detection is generally done with motor feedback. This tells the PLC that the motor is not turning when the contacts are closed. Adding and additional device should only be required if a risk assessment or some other qualitative justification shows that it is necessary. Motor feedback will be highly effective, we can only see flow measurement necessary in the event that the fan blades break or something (highly unlikely), and generally the motor will over amp/shutoff at that point, hence motor feedback will be effective.

The HEE sub-group wanted to allow the designer to choose the most suitable technology to meet the prescriptive requirement for ventilation monitoring.





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7.1.23.14.4

* A device shall be provided to detect failure of the ventilation system.

7.1.23.14.4.1

The device shall activate the ESS when airflow drops below 75 percent of the required flow ventilation preformace threshold

new annex note; The ventiateion system, 75% performance threshold, and means to monitor the ventilation system should be determined by the systemdesigner through a risk assessment .


HEE sub-group Substantiation Statement:Airflow sensors are too proscriptive and functionally problematic in practice. Motor control feedback to the PLC and motor overload controls are an effective way to determine if ventilation systems are functioning.

Loss of Ventilation detection is generally done with motor feedback. This tells the PLC that the motor is not turning when the contacts are closed. Adding and additional device should only be required if a risk assessment or some other qualitative justification shows that it is necessary.Motor feedback will be highly effective, we can only see flow measurement necessary in the event that the fan blades break or something (highly unlikely), and generally the motor will over amp/shutoff at that point, hence motor feedback will be effective.

Adding an additional device such a flow sensor should only be required if a risk assessment or some other qualitative justification shows that it is necessary. Motor feedback will be highly effective, we can only see flow measurement necessary in the event that the fan blades break or something (highly unlikely), and generally the motor will over amp/shutoff at that point, hence motor feedback will be effective.

The HEE sub-group wanted to allow the designer to choose the most suitable technology to meet the prescriptive requirement for ventilation monitoring.



Public Input No. 309-NFPA 2-2016 [New Section after A.7.1.23.9.2]




Affilliation: BoydH2 on behalf of Linde and NFPA 2 TG on HEEs

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Ignition sources in areas containing [GH2] shall be in accordance with 7.1.26 . [ 55: 7.6.3] addressed and where possible eliminated.


7.1.26 sending to 7.1.26 (itself), change it to some meat.




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Public Input No. 409-NFPA 2-2016 [ Sections 7.1.26, 7.1.27, 7.1.28 ]

Sections 7.1.26, 7.1.27, 7.1.28

7.1.26 Ignition Source Control.

Ignition sources in areas containing [GH2] shall be in accordance with 7.1.26. [55:7.6.3]

7.1.26.1 Static Producing Equipment.

Static producing equipment located in [GH2] areas shall be grounded. [55:7.6.3.1]

7.1.26.2 No Smoking or Open Flame.

Signs Labels shall be posted in areas containing [GH2] stating that smoking or the use of open flame, or both, is prohibited within 25 ft (7.6 m) of the

storage or use area perimeter. [55:7.6.3.2]

7.1.27 Operating Instructions.

(A)

For installations that require any operation of equipment by the user, the user shall be instructed in the operation of the equipment and emergencyshutdown procedures. [55:10.2.6.1.1]

(B)

Instructions shall be maintained at the operating site at a location acceptable to the authority having jurisdiction. [55:10.2.6.1.2]

7.1.28 Maintenance.

7.1.28.1


7.1.28.2

The maintenance shall include inspection for physical damage, leak tightness, ground system integrity, vent system operation, equipment identification,warning signs warning labels , operator information and training records, scheduled maintenance and retest records, alarm operation, and other safety-related features. [55:10.2.6.2.2]

7.1.28.3



OSHA regulates safety signs at CFR 1910.145. In addition to the OSHA language there is a reference to ANSI Z535. If the posted warnings in this code require 'signs' correlation with the OSHA and ANSI Z535 requirements is necessary. Specifying differing colors and other sign requirements in this code causes conflict with the OSHA requirements and a lack of warning consistency.

OSHA does not have requirements for 'labels'. As an alternative solution this proposal suggests replacing the word 'sign' with the word 'label' as one method of eliminating the conflict. Or the committee could choose to do a more extensive correlation by ensuring correlation with the OSHA requirements for signs. Whichever path the committee chooses it would need to be addressed throughout the code.





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7 6 . 1.28 22 Maintenance. 7

6 . 1 22 . 28. 1


7 6 . 1 22 . 28. 2

The maintenance shall include inspection for physical damage, leak tightness, ground system integrity, vent system operation, equipment identification,warning signs, operator information and training records, scheduled maintenance and retest records, alarm operation, and other safety-related features.[55:10.2.6.2.2]

7 6 . 1 22 . 28. 3



As currently written, the maintenance of hydrogen systems would be required annually for all systems regardless of whether the quantities are less than or greater than Maximum Allowable Quantity (MAQ). This is a significant change from the maintenance philosophy in the previous edition of NFPA 2 where it was required only for bulk systems over the MAQ.

Changing section number puts this requirement in a section that would only be required if the quantities are greater than the MAQ. This would make the requirement consistent with annual maintenance requirement for flammable gas systems found in NFPA 400 (2016 Edition) section 21.3.6.5.


Submitter Full Name: Neal Hara

Organization: Battelle-Pacific Northwest National Laboratory

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Submittal Date: Fri Apr 08 14:25:55 EDT 2016


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7.2.2.1.2 Classification of Weather Protection as an Indoor Versus Outdoor Area.

For other than explosive materials and hazardous materials presenting a detonation hazard, a weather protection structure shall Weather protectionstructures shall not be permitted to be used for sheltering outdoor storage or use areas without requiring such areas to be classified as indoor storage.[ 55: 7.2.1.3]


This is chapter is gaseous hydrogen. What does this mean for hydrogen?




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7.2.2.3.2 Distance to Exposures.

The outdoor storage or use of [GH2] shall be located from lot lines, public streets, public alleys, public ways, or buildings not associated with the

manufacture or distribution of [GH2] in accordance with Table 7.2.2.3.2. [55:7.6.2]

Table 7.2.2.3.2 Distance to Exposures for Non–Bulk [GH2]

Maximum AmountPer Storage Area

(ft3)

MinimumDistance Between

Storage Areas

(ft)

Minimum Distance toLot Lines of Property

That Can Be Built Upon

(ft)

Minimum Distance toPublic Streets, PublicAlleys, or Public Ways

(ft)

Minimum Distance to Buildings on the SameProperty

Less Than 2-HourConstruction

2-HourConstruction

4-HourConstruction

0–4225 5 5 5 5 0 0

4226–21,125 10 10 10 10 5 0

21,126–50,700 10 15 15 20 5 0

50,701–84,500 10 20 20 20 5 0

84,501–200,000 20 25 25 20 5 0

For SI units: 1 ft = 304.8 mm; 1 scf = 0.02832 Nm3.

Note: The minimum required distances shall not apply when fire barriers without openings or penetrations having a minimum fire resistive rating of 2 hoursinterrupt the line of sight between the storage and the exposure. The configuration of the fire barriers shall be designed to allow natural ventilation toprevent the accumulation of hazardous gas concentrations.

[55: Table 7.6.2]

7.2.2.3.2.1 Fire Barriers.

(A)*

Where a fire barrier is used to protect [ GH 2 GH2 ] systems, a source valve shall be installed upstream of the system shall terminate downstream of the

source valve. [ 55: 7.5.2.1.1] to isolate the flow of hydrogen into the system

(B)

The fire barrier wall shall be either an independent structure or the exterior wall of the building adjacent to the storage or use area. [55:7.5.2.1.2]

(C)

The fire barrier wall shall be without openings or penetrations. [55:8.7.2.1.1]

(1) Penetrations of the fire barrier wall by conduit or piping shall be permitted provided that the penetration is protected with a firestop system inaccordance with the [adopted] building code. [55:8.7.2.1.1.1]

(D)

The configuration of the [fire barrier] shall be designed to allow natural ventilation to prevent the accumulation of hazardous gas concentrations. [55:7.6.2.3]


Storage and use of [ GH 2 GH2 ] shall not be located within 50 ft 50 ft (15. 2 m 2 m ) of air intakes . [ 55: 7.6.2.4] unless obstructed by a sturdy partition

with a 2-hr fire rating, in which the distance can be reduced to at least 4.6 m (15 ft).


Storage and use of [ GH 2 GH2 ] outside of buildings shall also be separated from building openings by 25 ft 25 ft (7. 6 m). 6 m) unless obstructed by a

sturdy partition with a 2-hr fire rating, in which the distance can be reduced to at least 4.6 m (15 ft). Fire barriers shall be permitted to be used as a meansto separate storage areas from openings or a means of egress used to access the public way. [ 55: 7.6.2.5]


7.2.2.3.2.1 Confusing statement, unclear requirement. Hopes this clarifies.

7.2.2.3.2.12&3 The NFPA installation standards for special appliances has historically allowed shorted distances for a number of decades with the implicit assumption of a minimal velocity head release. Eliminate the direct impingement concern and the distance can be reduced. For example; “The exhaust outlet(s) from process areas or areas that contain fuel-bearing components of a fuel cell power system shall be located at least 4.6 m (15 ft) from heating, ventilating, and air-conditioning (HVAC) air intakes, windows, doors, and other openings into buildings”. [853:5.2.3]




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Storage and use of [GH2] outside of buildings shall also be separated from building openings by 25 ft (7.6 m). Fire barriers shall be permitted to be used as



The NFPA installation standards for special appliances has historically allowed shorted distances for a number of decades with the implicit assumption of a minimal velocity head release. Eliminate the direct impingement concern and the distance can be reduced. For example; “The exhaust outlet(s) from process areas or areas that contain fuel-bearing components of a fuel cell power system shall be located at least 4.6 m (15 ft) from heating, ventilating, and air-conditioning (HVAC) air intakes, windows, doors, and other openings into buildings”. [853:5.2.3]




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This section is use not storage. Non-bulk storage is 7.2.2.




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7.2.4.2 Carts and Trucks.

7.2.4.2.1

Cylinders Transportable cylinder , containers, and tanks shall be moved using an approved method. [ 55: 7.3.3.2.1] a commercially (or historically)accepted method.

7.2.4.2.2

Where transportable cylinders, containers, and tanks are moved by hand cart, hand truck, or other mobile device, such carts, trucks, or devices shall bedesigned for the secure movement of cylinders, containers, and tanks. [55:7.3.3.2.2]


1. We need to differentiate between stationary and transportable storage. An ASME cylinder or a DOT3AA are examples transportable storage.

2. What is “an approved method”, who approved the method? Commercially accepted is a best practice that has been historical demonstrated to be adequate.




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7.3.2.2.1

The location of bulk [GH 2 ] systems shall be in accordance with Table 7.3.2.2.1 . [ 55: 10.4.5.1.1].

Table 7.3.2.2.1 Location of [GH 2 ] Systems

Quantity of Hydrogen Location ≥5000 scf to <15,000 scf (≥142Nm 3 to <425 Nm 3 ) ≥15,000 scf (≥425 Nm 3 ) In a detached building A A In a gas room, inaccordance with Section 6.4 A Detached building required Not in a gas room NA Detached building required


[ 55: Table 10.4.5.1.1] Large bulk systems 15000 scf (425 Nm 3 ) or larger shall be located in a detached building. Small bulk systems of 5000 to 15000 scf(142 to 425 Nm3) shall be located in either a detached building or a gas room per section 6.4. Volumes less than 5000 scf are not considered bulk storageand are addressed in 7.2.2.

7.3.2.2.2 Detached Buildings.

7.3.2.2.2.1

Detached buildings shall be constructed of noncombustible or limited-combustible materials in accordance with the requirements of Section 6.5.[55:10.4.5.2.1]

7.3.2.2.2.2

Ventilation shall be provided in accordance with the requirements of Section 6.17. [55:10.4.5.2.2]

(A)

Outlet openings shall be located at the high point of the room in exterior walls or roof. [55:10.4.5.2.2.1]

(B)

Inlet and outlet openings shall each have a minimum total area of 1 ft2/1000 ft3 (1 m2/305 m3) of room volume. [55:10.4.5.2.2.2]

(C)

Discharge from outlet openings shall be directed or conducted to the atmosphere. [55:10.4.5.2.2.3]

7.3.2.2.2.3*


7.3.2.2.2.4


7.3.2.2.2.5

Heating, if provided, shall be by steam, hot water, or other indirect means except that electrical heating shall be permitted to be used if in compliance with7.3.2.2.2.4. [55:10.4.5.2.5]

7.3.2.2.3 Hydrogen Gas Rooms.

7.3.2.2.3.1

Floors, walls, and ceilings shall be constructed of noncombustible or limited-combustible materials in accordance with the requirements of the [adopted]building code. [55:10.4.5.3.1]

(A)

Interior walls or partitions shall have a fire resistance rating of not less than 2 hours, shall be continuous from floor to ceiling, and shall be anchored to resistmovement. [55:10.4.5.3.1.1]

(B)

Not less than 25 percent of the perimeter wall shall be an exterior wall. [55:10.4.5.3.1.2]

(C)

Openings to other parts of the building shall not be permitted. [55:10.4.5.3.1.3]

(D)

Windows and doors shall be in exterior walls only. [55:10.4.56.3.1.4]

7.3.2.2.3.2

Ventilation shall be as provided in 6.17. [55:10.4.5.3.2]

7.3.2.2.3.3


7.3.2.2.3.4

There shall be no sources of ignition from open flames, electrical equipment, or heating equipment. [55:10.4.5.3.4]

7.3.2.2.3.5*


7.3.2.2.3.6

Heating, if provided, shall be by steam, hot water, or indirect means except that electrical heating shall be permitted to be used if in compliance with7.3.2.2.3.5. [55:10.4.5.3.6]



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Lose the table, it is confusing. In this case text is more understandable. Also have the 15000 scf a soft limit otherwise there will be gamesmanship to get under the hard limit.




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7.3.2.2.2.2

Ventilation shall be provided in accordance with the requirements of Section 6.17. [ 55: 10.4.5.2.2]

(A)

Outlet openings shall be located at the high point of the room in exterior walls or roof. [ 55: 10.4.5.2.2.1]

(B)

Inlet and outlet openings shall each have a minimum total area of 1 ft 2 /1000 ft 3 (1 m 2 /305 m 3 ) of room volume. [ 55: 10.4.5.2.2.2]

(C)

Discharge from outlet openings shall be directed or conducted to the atmosphere. [ 55: 10.4.5.2.2.3]












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The minimum distance from a [GH2] system located outdoors to specified exposures shall be in accordance with Table 7.3.2.3.1.1(a) ,Table 7.3.2.3.1.1(b)

or Table 7.3.2.3.1.1(c) . [55:10.4.2.2.1]


(2) The separation distance for piping systems with internal diameters other than those specified in Table 7.3.2.3.1.1(a) for the pressure rangeselected shall be permitted with tabular distances determined based on the use of the equations in Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c) .[ 55: 10.4.2.2.1.1]

(3) Separation distances determined based on the use of Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c) shall be subject to review and approval bythe AHJ. [ 55: 10.4.2.2.2.2]

(4)

(5)

Table 7.3.2.3.1.1(a) Minimum Distance (D) from Outdoor [GH 2 ] Systems to Exposures — Typical Maximum Pipe Size

Pressure > 15 to ≤ 250 psig > 250 to ≤ 3000 psig > 3000 to ≤ 7500 psig > 7500 to ≤ 15000 psig Internal Pipe Diameter (ID) >103.4 to ≤ 1724 kPa >1724 to ≤20,684 kPa >20,684 to ≤ 51,711 kPa >51,711 to ≤ 103,421 kPa d mm d = 52.5 mm d = 18.97 mm d = 7.31 mm d = 7.16 mm Exposures

Group 1 m ft m ft m ft m ft (a) Lot lines 12 40 14 46 9 29 10 34 (b) Air intakes (HVAC, compressors, other) (c) Operable openings in buildingsand structures (d) Ignition sources such as open flames and welding Exposures Group 2 m ft m ft m ft m ft (a) Exposed persons other thanthose servicing the system 6 20 7 24 4 13 5 16 (b) Parked cars Exposures Group 3 m ft m ft m ft m ft (a) Buildings of non-combustiblenon-fire-rated construction 5 17 6 19 4 12 4 14 (b) Buildings of combustible construction (c) Flammable gas storage systems above or below ground (d)Hazardous materials storage systems above or below ground (e) Heavy timber, coal, or other slow-burning combustible solids (f) Ordinary combustibles,including fast-burning solids such as ordinary lumber, excelsior, paper, or combustible waste and vegetation other than that found in maintained landscapedareas (g) Unopenable openings in building and structures (h) Encroachment by overhead utilities (horizontal distance from the vertical plane Below thenearest overhead electrical wire of building service) (i) Piping containing other hazardous materials (j) Flammable gas metering and regulating stationssuch as natural gas or propane.

[ 55: Table 10.4.2.2.1(a)]

Table 7.3.2.3.1.1(b) Minimum Distance (D) from Outdoor [GH 2 ] Systems to Exposures by Maximum Pipe Size with Pressures >15 to ≤3000 psig

Pressure >15 to ≤250 psig

>103.4 to ≤1724 kPa >250 to ≤3000 psig

>17.24 to ≤20,684 kPa Exposures*† Exposures*† Internal Pipe Diameter (ID) Group 1 Group 2 Group 3 Group 1 Group 2 Group 3 D = 0.231d D = 0.12584d− 0.47126 D = 0.096d D = 0.738d D = 0.43616d − 0.91791 D = 0.307d ID (in.) d (mm) m ft m ft m ft m ft m ft m ft0.2 5.1 1 4 0 1 0 2 4 12 1 4 2 5 0.3 7.6 2 6 0 2 1 2 6 18 2 8 2 8 0.4 10.2 2 8 1 3 1 3 7 25 4 12 3 10 0.5 12.7 3 10 1 4 1 4 9 31 5 15 4 13 0.6 15.2 4 12 1 5 1 5 11 37 6 19 5




[ 55: Table 10.4.2.2.1(b)]

Table 7.3.2.3.1.1(c) Minimum Distance (D) from Outdoor [GH 2 ] Systems to Exposures by Maximum Pipe Size with Pressures >3000 to ≤15,000 psig

Pressure >3000 to ≤7500 psig

>20,684 to ≤51,711 kPa >7500 to ≤15,000 psig

>51,711 to ≤103,421 kPa Exposures*† Exposures*† Internal Pipe Diameter (ID) Group 1 Group 2 Group 3 Group 1 Group 2 Group 3 ID (in.) d (mm) D= 1.105d D = 0.68311d − 1.3123 D = 0.459d D = 1.448d D = 1.448d D = 0.602d m ft m ft m ft m ft m ft m ft0.2 5.1 6 18 2 7 2 8 7 24 3 10 3 10 0.3 7.6 8 28 4 13 3 11 11 36 5 18 5 15 0.4 10.2 11 37 6 18 5 15 15 48 8 25 6 20 0.5 12.7 14 46 7 24 6 19 18 60 10 33 8 25 0.6 15.2




[ 55: Table 10.4.2.2.1(c)]

Additional Proposed Changes

File Name Description Approved

Table_A.docx Table a

Table_b.docx table b

Table_c.docx Table c


* Determination of Internal Diameter. The internal diameter of the piping system shall be determined by the diameter of the piping serving

that portion of a storage array with content greater than 5000 scf (141.6 Nm 3 ). The piping system size used in the application of Table7.3.2.3.1.1(a) , Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c) and shall be determined based on that portion of the system with the greatestmaximum internal diameter. [ 55: 10.4.2.2.2.1]

* Determination of System Pressure. The system pressure shall be determined by the maximum operating pressure of the storage array

with content greater than 5000 scf (141.6Nm 3 ), irrespective of those portions of the system elevated to a higher pressure. [ 55: 10.4.2.2.3]


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Table designs are confusing. Replace with suggestions below:

Table 7.3.2.3.1.1(a) This table is confusing. Suggest the following format, using a soft conversion on pressure. Also is the minimum pressure needed? We could say for pressures exceeding 15 psig (105 kPa) in the table title.

Table 7.3.2.3.1.1 (b) & (c)

Suggest the following format, using a soft conversion on pressure. Also is the minimum pressure needed? We could say for pressures exceeding 0.103 MPa in the table title.

Additionally, I’m pretty sure the equation for 7500 to 15000 psig Group 2 is incorrect. It is the same as Group 1 but the distances are different.

Finally, using 0 for distances less than 1 meter allows line on line contact which is not the intent. Replacing with 0.3 or 0.6 means a minimum separation of 1or 2 ft and is in keeping with the next table.




Street Address:

City:

State:

Zip:



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Table 7.3.2.3.1.1(a) Table 7.3.2.3.1.1(a) Minimum Distance (D) from Outdoor [GH2] Systems to Exposures Typical Maximum Pipe Size

Pressure Customary - psig Metric - kPa minimum 15 250 3000 7500 105 1725 20700 51,700 maximum 250 3000 7500 15,000 1725 20700 51700 103400

Customary - inches Metric - mm Internal Pipe Diameter 2.067 0.747 0.288 0.282 52.5 18.97 7.31 7.16

Customary - feet Metric - meters Group 1 Exposure 40 46 29 34 12 14 9 10

(a) Lot lines (b) Air intakes (HVAC, compressors, other) (c) Operable openings in buildings and structures (d) Ignition sources such as open flames and welding

Group 2 Exposure 20 24 13 16 6 7 4 5 (a) Exposed persons other than those servicing the system (b) Parked cars

Group 3 Exposure 17 19 12 14 5 6 4 4 (a) Buildings of noncombustible non-fire-rated construction (b) Buildings of combustible construction (c) Flammable gas storage systems above or below ground (d) Hazardous materials storage systems above or below ground (e) Heavy timber, coal, or other slow-burning combustible solids (f) Ordinary combustibles, including fast-burning solids such as ordinary lumber, excelsior, paper, or combustible waste and vegetation other than that found in maintained landscaped areas (g) Unopenable openings in building and structures (h) Encroachment by overhead utilities (horizontal distance from the vertical plane below the nearest overhead electrical wire of building service) (i) Piping containing other hazardous materials (j) Flammable gas metering and regulating stations such as natural gas or propane

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Table b Table 7.3.2.3.1.1 (b) Maximum Distances from Outdoor Gaseous Hydrogen Systems to Exposure by Maximum Internal Pipe Diameter for pressures from >15 to <15,000 PSIG 103.4 kPa to 103.4 MPa (SI Units)

Pressure - MPa minimum 0.103 1.724 20.68 7500 maximum 1.724 20.68 51.71 103.4 Group 1 2 3 1 2 3 1 2 3 1 2 3

Internal Diameter (mm.) Minimum Distance - meters 5.1 1 0

0.3 0

0.6 4 1 2 6 2 2 7 3 3

7.6 2 0 0.6

1 6 2 2 8 4 3 11 5 5

10.2 2 1 1 7 4 3 11 6 5 15 8 6 12.7 3 1 1 9 5 4 14 7 6 18 10 8 15.2 4 1 1 11 6 5 17 9 7 22 12 9 17.8 4 2 2 13 7 5 20 11 8 26 15 11 20.3 5 2 2 15 8 6 22 13 9 29 17 12 22.9 5 2 2 17 9 7 25 14 10 33 20 14 25.4 6 3 2 19 10 8 28 16 12 37 22 15 27.9 6 3 3 21 11 9 31 18 13 40 24 17 30.5 7 3 3 22 12 9 34 20 14 44 27 18 33.0 8 4 3 24 13 10 36 21 15 48 29 20 35.6 8 4 3 26 15 11 39 23 16 51 31 21 38.1 9 4 4 28 16 12 42 25 17 55 34 23 40.6 9 5 4 30 17 12 45 26 19 59 36 24 43.2 10 5 4 32 18 13 48 28 20 63 38 26 45.7 11 5 4 34 19 14 51 30 21 66 41 28 48.3 11 6 5 36 20 15 53 32 22 70 43 29 50.8 12 6 5 37 21 16 56 33 23 74 46 31 53.3 12 6 5 39 22 16

Note: Linear interpolation of internal pipe diameters and distances between table entries is allowed. * For a list of exposures in each exposure group, see Column 1 of Table 7.3.2.3.1.1(a). † When calculating the minimum separation distance (D) using the formulas indicated, based on the exposure group and

pressure indicated, the internal pipe diameter (d) is entered in millimeters (mm). The calculated distance (D) is expressed in units of measure in meters (m).]

** The equations used for this table

D = (x * D) + y Where

D = Minimum Distance (meters) ID = Internal Diameter (millimeters) x = Function Slope

Function Slope - x Group 1 2 3

Pressure 0.103 to 1.724 MPa 0.231 0.12584 0.096 1.724 to 20.68 MPa 0.738 0.43616 0.307 20.68 to 51.71 MPa 1.105 0.68311 0.459 51.71 to 103.4 MPa 1.448 1.448 0.602

y = Function intercept

Function Intercept - y Group 1 2 3

Pressure 0.103 to 1.724 MPa 0 -0.47126 0 1.724 to 20.68 MPa 0 -0.91791 0 20.68 to 51.71 MPa 0 -1.3123 0 51.71 to 103.4 MPa 0 0 0

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Table c Table 7.3.2.3.1.1 (c) Maximum Distances from Outdoor Gaseous Hydrogen Systems to Exposure by Maximum Internal Pipe Diameter for pressures from >15 to <3000 PSIG to 15,000 PSIG (Customary Units)

Pressure - psig minimum 15 250 3000 7500 maximum 250 3000 7500 15,000

Group 1 2 3 1 2 3 1 2 3 1 2 3 Internal Diameter (in.) Minimum Distance - feet

0.2 4 1 2 12 4 5 18 7 8 24 10 10 0.3 6 2 2 18 8 8 28 13 11 36 18 15 0.4 8 3 3 25 12 10 37 18 15 48 25 20 0.5 10 4 4 31 15 13 46 24 19 60 33 25 0.6 12 5 5 37 19 15 55 30 23 72 41 30 0.7 13 6 6 43 22 18 64 36 27 84 49 35 0.8 15 7 6 49 26 20 74 41 31 97 56 40 0.9 17 8 7 55 30 23 83 47 34 109 64 45 1.0 19 9 8 62 33 26 92 53 38 121 72 50 1.1 21 10 9 68 37 28 101 58 42 131 80 55 1.2 23 11 10 74 41 31 111 64 46 145 87 60 1.3 25 12 10 80 44 33 120 70 50 157 95 65 1.4 27 13 11 86 48 36 129 75 54 169 103 70 1.5 29 14 12 92 52 38 138 81 57 181 111 75 1.6 31 15 13 98 55 41 147 87 61 193 118 80 1.7 33 16 14 105 59 43 157 92 65 205 126 85 1.8 35 17 14 111 62 46 166 98 69 217 134 90 1.9 37 18 15 117 66 49 175 104 73 229 142 95 2.0 39 19 16 123 70 51 184 110 77 241 149 100 2.1 40 20 17 129 73 54

Note: Linear interpolation of internal pipe diameters and distances between table entries is allowed. * For a list of exposures in each exposure group, see Column 1 of Table 7.3.2.3.1.1(a). † When calculating the minimum separation distance (D) using the formulas indicated in the notes

for Table 7.3.2.3.1.1(b) in SI units and then convert to customary units. feet, multiply the value in meters by 3.2808 and round to the nearest whole foot.

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SEE SUBSTANTIATION FOR CHANGES TO NUMBERING. THIS WAS A PC HELD FROM LAST CYCLE.



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The minimum distance from a [GH2] system located outdoors to specified exposures shall be in accordance with Table 7.3.2.3.1.1(a) ,Table 7.3.2.3.1.1(b)

or Table 7.3.2.3.1.1(c) . [55:10.4.2.2.1]


(2) The separation distance for piping systems with internal diameters other than those specified in Table 7.3.2.3.1.1(a) for the pressure rangeselected shall be permitted with tabular distances determined based on the use of the equations in Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c) .[ 55: 10.4.2.2.1.1]

(3) Separation distances determined based on the use of Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c) shall be subject to review and approval bythe AHJ. [ 55: 10.4.2.2.2.2]

(4)

(5)



> 250 to ≤3000 psig

> 3000 to ≤7500 psig

> 7500 to ≤15000 psig

Internal Pipe Diameter (ID)>103.4 to ≤1724 kPa

>1724 to ≤20,684 kPa

>20,684 to ≤51,711 kPa

>51,711 to ≤103,421 kPa

d mm d = 52.5 mm d = 18.97 mm d = 7.31 mm d = 7.16 mm


(a) Lot lines 12 40 14 46 9 29 10 34





(a) Exposed persons other than those servicing the system 6 20 7 24 4 13 5 16

(b) Parked cars


(a) Buildings of non-combustible non-fire-rated construction 5 17 6 19 4 12 4 14





(f) Ordinary combustibles, including fast-burning solids such as ordinary lumber,excelsior, paper, or combustible waste and vegetation other than that found inmaintained landscaped areas


(h) Encroachment by overhead utilities (horizontal distance from the vertical planeBelow the nearest overhead electrical wire of building service)


(j) Flammable gas metering and regulating stations such as natural gas or propane.

[55:Table 10.4.2.2.1(a)]

Table 7.3.2.3.1.1(b) Minimum Distance (D) from Outdoor [GH2] Systems to Exposures by Maximum Pipe Size with Pressures >15 to ≤3000 psig

Pressure

>15 to ≤250 psig

>103.4 to ≤1724 kPa

>250 to ≤3000 psig

>17.24 to ≤20,684 kPa




D = 0.231dD = 0.12584d −

0.47126D = 0.096d D = 0.738d

D = 0.43616d −0.91791

D = 0.307d

ID (in.) d (mm) m ft m ft m ft m ft m ft m ft

0.2 5.1 1 4 0 1 0 2 4 12 1 4 2 5

0.3 7.6 2 6 0 2 1 2 6 18 2 8 2 8

0.4 10.2 2 8 1 3 1 3 7 25 4 12 3 10

0.5 12.7 3 10 1 4 1 4 9 31 5 15 4 13

0.6 15.2 4 12 1 5 1 5 11 37 6 19 5 15

0.7 17.8 4 13 2 6 2 6 13 43 7 22 5 18

0.8 20.3 5 15 2 7 2 6 15 49 8 26 6 20

* Determination of Internal Diameter. The internal diameter of the piping system shall be determined by the diameter of the piping serving

that portion of a storage array with content greater than 5000 scf (141.6 Nm 3 ). The piping system size used in the application of Table7.3.2.3.1.1(a) , Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c) and shall be determined based on that portion of the system with the greatestmaximum internal diameter. [ 55: 10.4.2.2.2.1]

* Determination of System Pressure. The system pressure shall be determined by the maximum operating pressure of the storage array

with content greater than 5000 scf (141.6Nm 3 ), irrespective of those portions of the system elevated to a higher pressure. [ 55: 10.4.2.2.3]


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Pressure

>15 to ≤250 psig

>103.4 to ≤1724 kPa

>250 to ≤3000 psig

>17.24 to ≤20,684 kPa




D = 0.231dD = 0.12584d −

0.47126D = 0.096d D = 0.738d

D = 0.43616d −0.91791

D = 0.307d

0.9 22.9 5 17 2 8 2 7 17 55 9 30 7 23

1.0 25.4 6 19 3 9 2 8 19 62 10 33 8 26

1.1 27.9 6 21 3 10 3 9 21 68 11 37 9 28

1.2 30.5 7 23 3 11 3 10 22 74 12 41 9 31

1.3 33 8 25 4 12 3 10 24 80 13 44 10 33

1.4 35.6 8 27 4 13 3 11 26 86 15 48 11 36

1.5 38.1 9 29 4 14 4 12 28 92 16 52 12 38

1.6 40.6 9 31 5 15 4 13 30 98 17 55 12 41

1.7 43.2 10 33 5 16 4 14 32 105 18 59 13 43

1.8 45.7 11 35 5 17 4 14 34 111 19 62 14 46

1.9 48.3 11 37 6 18 5 15 36 117 20 66 15 49

2.0 50.8 12 39 6 19 5 16 37 123 21 70 16 51

2.1 53.3 12 40 6 20 5 17 39 129 22 73 16 54



†When calculating the minimum separation distance (D) using the formulas indicated, based on the exposure group and pressure indicated, the internalpipe diameter (d) is entered in millimeters (mm). The calculated distance (D) is expressed in units of measure in meters (m). To convert distance (D) to unitsof measure in feet, multiply the value of (D) in meters by 3.2808 and round to the nearest whole foot.

[55:Table 10.4.2.2.1(b)]

Table 7.3.2.3.1.1(c) Minimum Distance (D) from Outdoor [GH2] Systems to Exposures by Maximum Pipe Size with Pressures >3000 to ≤15,000 psig

Pressure

>3000 to ≤7500 psig

>20,684 to ≤51,711 kPa

>7500 to ≤15,000 psig

>51,711 to ≤103,421 kPa




ID (in.) d (mm)

D = 1.105dD = 0.68311d −

1.3123 D = 0.459d D = 1.448d D = 1.448d D = 0.602d


0.2 5.1 6 18 2 7 2 8 7 24 3 10 3 10

0.3 7.6 8 28 4 13 3 11 11 36 5 18 5 15

0.4 10.2 11 37 6 18 5 15 15 48 8 25 6 20

0.5 12.7 14 46 7 24 6 19 18 60 10 33 8 25

0.6 15.2 17 55 9 30 7 23 22 72 12 41 9 30

0.7 17.8 20 64 11 36 8 27 26 84 15 49 11 35

0.8 20.3 22 74 13 41 9 31 29 97 17 56 12 40

0.9 22.9 25 83 14 47 10 34 33 109 20 64 14 45

1.0 25.4 28 92 16 53 12 38 37 121 22 72 15 50

1.1 27.9 31 101 18 58 13 42 40 133 24 80 17 55

1.2 30.5 34 111 20 64 14 46 44 145 27 87 18 60

1.3 33.0 36 120 21 70 15 50 48 157 29 95 20 65

1.4 35.6 39 129 23 75 16 54 51 169 31 103 21 70

1.5 38.1 42 138 25 81 17 57 55 181 34 111 23 75

1.6 40.6 45 147 26 87 19 61 59 193 36 118 24 80

1.7 43.2 48 157 28 92 20 65 63 205 38 126 26 85

1.8 45.7 51 166 30 98 21 69 66 217 41 134 28 90

1.9 48.3 53 175 32 104 22 73 70 229 43 142 29 95

2.0 50.8 56 184 33 110 23 77 74 241 46 149 31 100



†When calculating the minimum separation distance (D) using the formulas indicated, based on the exposure group and pressure indicated, the internalpipe diameter (d) is entered in millimeters (mm). The calculated distance (D) is expressed in units of measure in meters (m). To convert distance (D) to unitsof measure in feet, multiply the value of (D) in meters by 3.2808 and round to the nearest whole foot.

[55:Table 10.4.2.2.1(c)]



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Held_PC_44.pdf NFPA 2 _PC 44

S._Goyette_Proposed_Changes_for_7.3.2.3.1_Minimum_Distance_for_Aboveground_Locations_-_MARK_UP_-_2014-05-14.1400081714685.pdf

MARK UP PROPOSED CHANGES

S._Goyette_Proposed_Changes_for_7.3.2.3.1_Minimum_Distance_for_Aboveground_Locations_-_FINAL_-_2014-05-14.1400081807860.pdf

FINAL VIEW OF PROPOSED CHANGES


NOTE: This Public Input appeared as "Reject but Hold" in Public Comment No. 44 of the (A2015 cycle) Second Draft Report for NFPA 2 and per the Regs. at 4.4.8.3.1.

This section did not flow (work) logically and was missing an enabler for one of the tables - reorganized. Since "(B), (C), (D), & (E)" have been moved to other sections or removed entirely, "(A)" is no longer necessary - removed to reduce number of indents and confusion re: numbering. Text was missing pointer to Table ...(c) - added. Moved "Determination of Internal Diameter" to top of list because this is the first information needed to use the tables. Moved permission to use equations under "Determination of Internal Diameter" to keep diameter related information together. Since tables allow extrapolation between diameters, changed wording to only allow equations for diameters greater than those in tables. Moved "Maximum Internal Diameter of Interconnect Piping" (exception for piping between shut off valve and storage) under "Determination of Internal Diameter" to keep diameter related information together. Moved "Determination of System Pressure" to 2nd in list because this is the second piece of information needed to use the tables. Moved "...subject to review and approval by the AHJ." to last because it applies to everything that comes before it. NOTE: This is totally unnecessary text. The laws that empower the AHJs trump anything in an NFPA code. Note: Need to update Annex A to correlate with numbering changes. Note: NFPA 55 should be updated as well.


Submitter Full Name: Tc On Hyd-Aaa

Organization: NFPA

Street Address:

City:

State:

Zip:



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Public Comment No. 44-NFPA 2-2014 [ Section No. 7.3.2.3.1.1 ]

7.3.2.3.1.1 * Minimum Distance for Aboveground Locations.

National Fire Protection Association Report http://submittalsarchive.nfpa.org/TerraViewWeb/FormLaunch?id=/Terra...

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(A) *


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The minimum distance from a [GH2] system located outdoors to specified exposures shall be in accordance

with Table 7.3.2.3.1.1(A)(a) a), Table 7.3.2.3.1.1(b), or Table 7.3.2.3.1.1(A c )(b) . (See also Annex I.)[55:10.3.2.1] Maximum

(1)

of Interconnecting Piping

(1)

maximum

(1)

used for interconnecting piping between the shutoff valve on any single storage container to the point ofconnection to the system source valve shall not be required to be in accordance with the values shown in

(1)

A)(

(1)

when in accordance with

(1)

A)(b)

(1)

(2)

other

(1)

(a)

.1

(1)

(a)

A)(a) for the pressure range selected shall be permitted with tabular distances determined based on the use ofthe equations in

(1)

(a)

A)(

(1)

(a)

A)(c) . .[ 55: 10.3.2.1.1]Separation distances

(1)

(a)

A

* Determination of Internal Diameter

. The

internal diameter of the piping system

shall be determined by the diameter of the piping serving that portion of a storage array with content

greater than 5000 scf (141.6 Nm 3 ). The piping system size used in the application of Table 7.3.2.3.1.1(

a)

, Table 7.3.2.3.1.1(

b), or Table 7.3.2.3.1.1(c) shall be determined based on that portion of the system with the greatestmaximum internal diameter . [ 55: 10.3.2.2 .1 ]

* The separation distance for piping systems with internal diameters

greater than those specified in Table 7.3.2.3.1

(

a), Table 7.3.2.3.1.1(

b) , or Table 7.3.2.3.1.1(

c) shall be determined based on the use of the equations in Table 7.3.2.3.1.1(


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(1)

(a)

(a)

(1)

(a)

A)(

(1)

(a)

shall be subject to review and approval by the AHJ.

(1)

(a)

2

(1)

(a)

2Determination of

(1)

(a)

(1)

(a)

shall be determined by the diameter of the piping serving that portion of a storage array with content greater

than 5000 scf (141.6 Nm 3 ). The piping system size used in the application of

(1)

(a)

A)(b) or

(1)

(a)

A)(c)and shall be determined based on that portion of the system with the greatest maximum internal diameter

(1)

(a)

.1

(1)

(a)

(2)

Table 7

b )

or Table 7.3.2.3.1.1(

c)

. . [ 55: 10.3.2.

1 .

1 ]

*

Maximum Internal Diameter of Interconnecting Piping . The maximum internal diameter of thepiping system

used for interconnecting piping between the shutoff valve on any single storage container to thepoint of connection to the system source valve shall not be required to be in accordance with thevalues shown in Table 7.3.2.3.1.1(

a) when in accordance with Table 7.3.2.3.1.1(

b) . [ 55: 10.3.2.2

]

* Determination of System Pressure. The system pressure shall be determined by the maximum

operating pressure of the storage array with content greater than 5000 scf (141.6Nm 3 ), irrespective ofthose portions of the system elevated to a higher pressure. [ 55: 10.3.2.3]


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(1)

A)(

(1)

Table 7.3.2.3.1.1( a) Minimum Distance (D) from Outdoor [GH 2 ] Systems to Exposures — Typical Maximum

Pipe Size


> 250 to ≤3000 psig

> 3000 to ≤7500 psig

> 7500 to ≤15000 psig

Internal Pipe Diameter (ID)>103.4 to

≤ 1724kPa

>1724 to≤ 20,684

kPa

>20,684 to≤ 51,711

kPa

>51,711 to≤ 103,421

kPa

d mmd = 52.5

mmd = 18.97

mmd = 7.31

mmd = 7.16

mm


(a) Lot lines 12 40 14 46 9 29 10 34





(a) Exposed persons other than those servicing thesystem 6 20 7 24 4 13 5 16

(b) Parked cars


(a) Buildings of non-combustible non-fire-ratedconstruction 5 17 6 19 4 12 4 14


(c) Flammable gas storage systems above or belowground

(d) Hazardous materials storage systems above or belowground

(e) Heavy timber, coal, or other slow-burning combustiblesolids

(f) Ordinary combustibles, including fast-burning solidssuch as ordinary lumber, excelsior, paper, or combustiblewaste and vegetation other than that found in maintainedlandscaped areas


(h) Utilities overhead including electric power, buildingservices or hazardous materials piping systems

[ 55: Table 10.3.2.1(a)]

Table 7.3.2.3.1.1(

A)(

b) Minimum Distance (D) from Outdoor [GH 2 ] Systems to Exposures by Maximum Pipe Size with Pressures

>15 to ≤3000 psig

Pressure

>15 to ≤250 psig

>103.4 to ≤1724 kPa>250 to ≤3000 psig >17.24 to ≤20,684 kPa


Separation distances determined based on the use of Table 7 .3.2.3.1.1(

a), Table 7.3.2.3.1.1(b), or Table 7.3.2.3.1.1(c) shall be subject to review and approval by the AHJ.[ 55: 10.3.2.2.2]


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D = 0.231dD = 0.12584d

− 0.47126D = 0.096d D = 0.738d

D = 0.43616d− 0.91791

D = 0.307d

ID(in.)

d(mm) m ft m ft m ft m ft m ft m ft

0.2 5.1 1 4 0 1 0 2 4 12 1 4 2 5

0.3 7.6 2 6 0 2 1 2 6 18 2 8 2 8

0.4 10.2 2 8 1 3 1 3 7 25 4 12 3 10

0.5 12.7 3 10 1 4 1 4 9 31 5 15 4 13

0.6 15.2 4 12 1 5 1 5 11 37 6 19 5 15

0.7 17.8 4 13 2 6 2 6 13 43 7 22 5 18

0.8 20.3 5 15 2 7 2 6 15 49 8 26 6 20

0.9 22.9 5 17 2 8 2 7 17 55 9 30 7 23

1.0 25.4 6 19 3 9 2 8 19 62 10 33 8 26

1.1 27.9 6 21 3 10 3 9 21 68 11 37 9 28

1.2 30.5 7 23 3 11 3 10 22 74 12 41 9 31

1.3 33 8 25 4 12 3 10 24 80 13 44 10 33

1.4 35.6 8 27 4 13 3 11 26 86 15 48 11 36

1.5 38.1 9 29 4 14 4 12 28 92 16 52 12 38

1.6 40.6 9 31 5 15 4 13 30 98 17 55 12 41

1.7 43.2 10 33 5 16 4 14 32 105 18 59 13 43

1.8 45.7 11 35 5 17 4 14 34 111 19 62 14 46

1.9 48.3 11 37 6 18 5 15 36 117 20 66 15 49

2.0 50.8 12 39 6 19 5 16 37 123 21 70 16 51

2.1 53.3 12 40 6 20 5 17 39 129 22 73 16 54


*For a list of exposures in each exposure group see Column 1 of Table 7.3.2.3.1.1(

A)(

a).

†When calculating the minimum separation distance (D) using the formulas indicated, based on the exposuregroup and pressure indicated, the internal pipe diameter (d) is entered in millimeters (mm). The calculateddistance (D) is expressed in units of measure in meters (m). To convert distance (D) to units of measure in feet,multiply the value of (D) in meters by 3.2808 and round to the nearest whole foot.

[ 55: Table 10.3.2.1(b)]

Table 7.3.2.3.1.1(

A)(

c) Minimum Distance (D) from Outdoor [GH 2 ] Systems to Exposures by Maximum Pipe Size with Pressures

>3000 to ≤15,000 psig

Pressure

>3000 to ≤7500 psig >20,684 to ≤51,711kPa

>7500 to ≤15,000 psig >51,711 to ≤103,421kPa




ID(in.)

d(mm) D = 1.105d

D = 0.68311d− 1.3123 D = 0.459d D = 1.448d D = 1.448d D = 0.602d


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Pressure

>3000 to ≤7500 psig >20,684 to ≤51,711kPa

>7500 to ≤15,000 psig >51,711 to ≤103,421kPa





0.2 5.1 6 18 2 7 2 8 7 24 3 10 3 10

0.3 7.6 8 28 4 13 3 11 11 36 5 18 5 15

0.4 10.2 11 37 6 18 5 15 15 48 8 25 6 20

0.5 12.7 14 46 7 24 6 19 18 60 10 33 8 25

0.6 15.2 17 55 9 30 7 23 22 72 12 41 9 30

0.7 17.8 20 64 11 36 8 27 26 84 15 49 11 35

0.8 20.3 22 74 13 41 9 31 29 97 17 56 12 40

0.9 22.9 25 83 14 47 10 34 33 109 20 64 14 45

1.0 25.4 28 92 16 53 12 38 37 121 22 72 15 50

1.1 27.9 31 101 18 58 13 42 40 133 24 80 17 55

1.2 30.5 34 111 20 64 14 46 44 145 27 87 18 60

1.3 33.0 36 120 21 70 15 50 48 157 29 95 20 65

1.4 35.6 39 129 23 75 16 54 51 169 31 103 21 70

1.5 38.1 42 138 25 81 17 57 55 181 34 111 23 75

1.6 40.6 45 147 26 87 19 61 59 193 36 118 24 80

1.7 43.2 48 157 28 92 20 65 63 205 38 126 26 85

1.8 45.7 51 166 30 98 21 69 66 217 41 134 28 90

1.9 48.3 53 175 32 104 22 73 70 229 43 142 29 95

2.0 50.8 56 184 33 110 23 77 74 241 46 149 31 100


*For a list of exposures in each exposure group see Column 1 of Table 7.3.2.3.1.1(

A)(

a).

†When calculating the minimum separation distance (D) using the formulas indicated, based on the exposuregroup and pressure indicated, the internal pipe diameter (d) is entered in millimeters (mm). The calculateddistance (D) is expressed in units of measure in meters (m). To convert distance (D) to units of measure in feet,multiply the value of (D) in meters by 3.2808 and round to the nearest whole foot.

[ 55: Table 10.3.2.1(c)]



S._Goyette_Proposed_Changes_for_7.3.2.3.1_Minimum_Distance_for_Aboveground_Locations_-_MARK_UP_-_2014-05-14.pdf

PDF of MARK UP of section using Word (showing proposed changes).

✓

S._Goyette_Proposed_Changes_for_7.3.2.3.1_Minimum_Distance_for_Aboveground_Locations_-_FINAL_-_2014-05-14.pdf

PDF of FINAL view of section

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using Word (showing proposed final version of changes without all the clutter).

Statement of Problem and Substantiation for Public Comment

This section did not flow (work) logically and was missing an enabler for one of the tables - reorganized.

Since "(B), (C), (D), & (E)" have been moved to other sections or removed entirely, "(A)" is no longer necessary - removed to reduce number of indents and confusion re: numbering.

Text was missing pointer to Table ...(c) - added.

Moved "Determination of Internal Diameter" to top of list because this is the first information needed to use the tables.

Moved permission to use equations under "Determination of Internal Diameter" to keep diameter related information together.Since tables allow extrapolation between diameters, changed wording to only allow equations for diameters greater than those in tables.

Moved "Maximum Internal Diameter of Interconnect Piping" (exception for piping between shut off valve and storage) under "Determination of Internal Diameter" to keep diameter related information together.

Moved "Determination of System Pressure" to 2nd in list because this is the second piece of information needed to use the tables.

Moved "...subject to review and approval by the AHJ." to last because it applies to everything that comes before it.NOTE: This is totally unnecessary text. The laws that empower the AHJs trump anything in an NFPA code.

Note: Need to update Annex A to correlate with numbering changes.

Note: NFPA 55 should be updated as well.

Related Public Comments for This Document

Related Comment Relationship

Public Comment No. 39-NFPA 2-2014 [NewSection after 13.2.6.3]

Outdoor Hydrogen Generator section refers to 7.3.2.3 forsepartion distances.

Public Comment No. 46-NFPA 2-2014 [Section No.A.7.3.2.3.1.1(A)]

This Annex A entry refers to section and tables modifiedby PC No. 44.

Public Comment No. 45-NFPA 2-2014 [Section No.7.3.2.3.1.2]

This PC references table designation changed by PC No.44.

Related Item

First Revision No. 362-NFPA 2-2013 [Section No. 7.3.2.3.1.1]


Submitter Full Name: Stephen Goyette

Organization: Nuvera Fuel Cells, Inc.

Affilliation: NFPA 2 Committee

Street Address:

City:


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State:

Zip:

Submittal Date: Wed May 14 09:51:08 EDT 2014

Committee Statement

CommitteeAction:

Rejected but held

Resolution: This comment will be held until the next cycle. Reorganization of this material should be submitted asa PI to 55. Note to staff and editorial to check the extracted material from NFPA 55

Copyright Assignment

I, Stephen Goyette, hereby irrevocably grant and assign to the National Fire Protection Association (NFPA) all and full rights in copyright in thisPublic Comment (including both the Proposed Change and the Statement of Problem and Substantiation). I understand and intend that I acquireno rights, including rights as a joint author, in any publication of the NFPA in which this Public Comment in this or another similar or derivativeform is used. I hereby warrant that I am the author of this Public Comment and that I have full power and authority to enter into this copyrightassignment.

By checking this box I affirm that I am Stephen Goyette, and I agree to be legally bound by the above Copyright Assignment and the termsand conditions contained therein. I understand and intend that, by checking this box, I am creating an electronic signature that will, upon mysubmission of this form, have the same legal force and effect as a handwritten signature


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S. Goyette Proposed Changes for 7.3.2.3.1.1 Minimum Distance for Aboveground Locations

Page 1 of 2

7.3.2.3 Outdoor Storage. 7.3.2.3.1 Aboveground Locations. 7.3.2.3.1.1* Minimum Distance for Aboveground Locations. (A)* The minimum distance from a [GH2] system located outdoors to specified exposures shall be in accordance with Table 7.3.2.3.1.1(A)(a), or Table 7.3.2.3.1.1(A)(b), or Table 7.3.2.3.1.1(c). (See

also Annex I.) [55:10.3.2.1]

1. Maximum Internal Diameter of Interconnecting Piping. The maximum internal diameter of the piping system used for interconnecting piping between the shutoff valve on any single storage container to the point of connection to the system source valve shall not be required to be in accordance with the values shown in Table 7.3.2.3.1.1(A)(a)when in accordance withTable 7.3.2.3.1.1(A)(b). [55:10.3.2.2]

1. * The separation distance for piping systems with internal diameters other than those specified in Table 7.3.2.3.1.1(A)(a) for the pressure range selected shall be permitted with tabular distances determined based on the use of the equations in Table 7.3.2.3.1.1(A)(b)or Table 7.3.2.3.1.1(A)(c) . .[55:10.3.2.1.1]

1. Separation distances determined based on the use of Table 7.3.2.3.1.1(A)(a) or Table 7.3.2.3.1.1(A)(c) shall be subject to review and approval by the AHJ. [55:10.3.2.2.2]

1. * Determination of Internal Diameter. The internal diameter of the piping system shall be determined by the diameter of the piping serving that portion of a storage array with content greater than 5000 scf (141.6 Nm3). The piping system size used in the application of Table 7.3.2.3.1.1(a), Table 7.3.2.3.1.1(b), or Table 7.3.2.3.1.1(c) Table 7.3.2.3.1.1(A)(b) or Table 7.3.2.3.1.1(A)(c)and shall be determined based on that portion of the system with the greatest maximum internal diameter. [55:10.3.2.2.1]

1. * The separation distance for piping systems with internal diameters othergreater than those specified in Table 7.3.2.3.1.1(A)(a), Table 7.3.2.3.1.1(b), or Table 7.3.2.3.1.1(c) for the pressure range selected shall be permitted with tabular distances determined based on the use of the equations in Table 7.3.2.3.1.1(A)(b) or Table 7.3.2.3.1.1(A)(c) . . [55:10.3.2.1.1]

2. Maximum Internal Diameter of Interconnecting Piping. The maximum internal diameter of the piping system used for interconnecting piping between the shutoff valve on any single storage container to the point of connection to the system source valve shall not be required to be in accordance with the values shown in Table 7.3.2.3.1.1(a) when in accordance with Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c). [55:10.3.2.2]

1.

2. * Determination of System Pressure. The system pressure shall be determined by the maximum operating pressure of the storage array with content greater than 5000 scf (141.6Nm3), irrespective of those portions of the system elevated to a higher pressure. [55:10.3.2.3]

3. Separation distances determined based on the use of Table 7.3.2.3.1.1(A)(a), Table 7.3.2.3.1.1(b), or Table 7.3.2.3.1.1(A)(c) shall be subject to review and approval by the AHJ. [55:10.3.2.2.2]

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Page 2 of 2

Table 7.3.2.3.1.1(A)(a) Minimum Distance (D) from Outdoor [GH2] Systems to Exposures — Typical Maximum Pipe Size

[55:Table 10.3.2.1(a)]

Table 7.3.2.3.1.1(A)(b) Minimum Distance (D) from Outdoor [GH2] Systems to Exposures

by Maximum Pipe Size with Pressures >15 to ≤3000 psig


*For a list of exposures in each exposure group see Column 1 of Table 7.3.2.3.1.1(A)(a).

†When calculating the minimum separation distance (D) using the formulas indicated, based on the exposure group and pressure indicated, the internal pipe diameter (d) is entered in millimeters (mm). The calculated distance (D) is expressed in units of measure in meters (m). To convert distance (D) to units of measure in feet, multiply the value of (D) in meters by 3.2808 and round to the nearest whole foot.

[55:Table 10.3.2.1(b)]

Table 7.3.2.3.1.1(A)(c) Minimum Distance (D) from Outdoor [GH2] Systems to Exposures

by Maximum Pipe Size with Pressures >3000 to ≤15,000 psig


*For a list of exposures in each exposure group see Column 1 of Table 7.3.2.3.1.1(A)(a).


[55:Table 10.3.2.1(c)]

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Page 1 of 2

7.3.2.3 Outdoor Storage. 7.3.2.3.1 Aboveground Locations. 7.3.2.3.1.1* Minimum Distance for Aboveground Locations. The minimum distance from a [GH2] system located outdoors to specified exposures shall be in accordance with Table 7.3.2.3.1.1(a), Table 7.3.2.3.1.1(b), or Table 7.3.2.3.1.1(c). (See also

Annex I.) [55:10.3.2.1]

1. * Determination of Internal Diameter. The internal diameter of the piping system shall be determined by the diameter of the piping serving that portion of a storage array with content greater than 5000 scf (141.6 Nm3). The piping system size used in the application of Table 7.3.2.3.1.1(a), Table 7.3.2.3.1.1(b), or Table 7.3.2.3.1.1(c) shall be determined based on that portion of the system with the greatest maximum internal diameter. [55:10.3.2.2.1]

1. * The separation distance for piping systems with internal diameters greater than those specified in Table 7.3.2.3.1.1(a), Table 7.3.2.3.1.1(b), or Table 7.3.2.3.1.1(c) shall be determined based on the use of the equations in Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c). [55:10.3.2.1.1]

2. Maximum Internal Diameter of Interconnecting Piping. The maximum internal diameter of the piping system used for interconnecting piping between the shutoff valve on any single storage container to the point of connection to the system source valve shall not be required to be in accordance with the values shown in Table 7.3.2.3.1.1(a) when in accordance with Table 7.3.2.3.1.1(b) or Table 7.3.2.3.1.1(c). [55:10.3.2.2]

2. * Determination of System Pressure. The system pressure shall be determined by the maximum operating pressure of the storage array with content greater than 5000 scf (141.6Nm3), irrespective of those portions of the system elevated to a higher pressure. [55:10.3.2.3]

3. Separation distances determined based on the use of Table 7.3.2.3.1.1(a), Table 7.3.2.3.1.1(b), or Table 7.3.2.3.1.1(c) shall be subject to review and approval by the AHJ. [55:10.3.2.2.2]

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Page 2 of 2


[55:Table 10.3.2.1(a)]

Table 7.3.2.3.1.1(b) Minimum Distance (D) from Outdoor [GH2] Systems to Exposures by

Maximum Pipe Size with Pressures >15 to ≤3000 psig




[55:Table 10.3.2.1(b)]

Table 7.3.2.3.1.1(c) Minimum Distance (D) from Outdoor [GH2] Systems to Exposures by

Maximum Pipe Size with Pressures >3000 to ≤15,000 psig




[55:Table 10.3.2.1(c)]

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Public Input No. 276-NFPA 2-2016 [ Section No. 7.3.2.3.1.2(A) ]

(A)*

Except for distances to air intakes, the distances to Group 1 and 2 exposures shown in Table 7.3.2.3.1.1(a),Table 7.3.2.3.1.1(b) and Table 7.3.2.3.1.1(c)shall be permitted to be reduced by one-half and shall not apply to Group 3 exposures where fire barrier walls are located between the system and theexposure and constructed in accordance with the following: [55:10.4.2.2.4.1]

(1) The fire barrier wall shall be without openings or penetrations. [55:8.7.3.2.1]

(2) Penetrations of the fire barrier wall by conduit or piping shall be permitted provided that the penetration is protected with a firestop system inaccordance with the [adopted] building code. [ 55: 8.7.3.2.1.1]

(3) Fire barrier walls shall have a minimum fire resistance rating of not less than 2 hours. [55:10.4.2.2.4.1(1)]

(4) The fire barrier wall shall interrupt the line of sight between the bulk hydrogen compressed gas system and the exposure. [55:10.4.2.2.4.1(2)]

(5) The configuration of the fire barrier shall allow natural ventilation to prevent the accumulation of hazardous gas concentrations. [55:10.4.2.2.4.1(3)]

(6) The number of fire barrier walls used to separate individual systems shall be limited to three. [55:10.4.2.2.4.1(4)]

(7) The fire barrier wall shall not have more than two sides at 90 degrees (1.57 rad) directions or not more than three sides with connecting angles of 135degrees (2.36 rad). [55:10.4.2.2.4.1(5)]

(8) The connecting angles between fire barrier walls shall be permitted to be reduced to less than 135 degrees (2.3 rad) for installations consistingof three walls when in accordance with 8.3.2.3.1.5(E) . [ 55: 10.4.2.2.4.1(5)(a)]

(9) Fire barrier walls shall be designed and constructed as a structure in accordance with the requirements of the building code without exceeding thespecified allowable stresses for the materials of construction utilized. Structures shall be designed to resist the overturning effects caused by lateralforces due to wind, soil, flood, and seismic events. [55:10.4.2.2.4.1(6)]

(10) Where clearance is required between bulk hydrogen compressed gas system and the barrier wall for the performance of service or maintenance-related activities, a minimum horizontal clearance of 5 ft (1.5 m) shall be provided between the structure and the system. [55:10.4.2.2.4.1(7)]

(11) The fire barrier wall shall be either an independent structure, the wall of a Hydrogen equipment enclosure, the wall of a court, or the exterior wall ofthe building adjacent to the storage or use area when the exterior building wall meets the requirements for fire barrier walls. [55:10.4.2.2.4.1(8)]


Hydrogen equipment enclosures and courts may include walls that are constructed of fire resistive material, and as long as they meet all the requirements of a fire barrier wall, they can be used to provide the same benefits of a fire barrier wall. For example, with this proposed text located as part of subparagraph (A), fire barrier walls need to meet the previously specified requirements, such as being constructed with a minimum 2 hour fire rating and interrupting the line of sight between the system and exposure. This is comparable to the existing language in subparagraph (9) which already refers to independent structures and exterior walls of buildings.

The HEE sub-group discussed this and with a few modifications settled on this as an effective means to satisfy additional barriers that may include the newly discussed courts in other public inputs. With an improved substantiation statement, we believe this will meet the needs of the TC moving forward.





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Public Input No. 310-NFPA 2-2016 [ New Section after 7.3.2.3.1.2(B) ]

7.3.2.3.1.2* Reduction of Distance by Mitigation Means. (new section C)

(C) Hydrogen Equipment Enclosures. When an HEE contains hydrogen storage, compressor, or controls systems inside a prefabricated system with four(4) walls and a roof, the distances to Group 1 and 2 exposures shown in Table 7.3.2.3.1.1(a), Table 7.3.2.3.1.1(b), and Table 7.3.2.3.1.1(c) shall bepermitted to be reduced by one-half and Group 3 exposures shall be permitted to be reduced to 5 feet (1.5 meter) where un-penetrated fire barrier walls ofthe HEE are facing the exposure and the HEE is constructed in accordance with the following:

(1) the HEE shall comply with the requirements in 7.1.23 including ventilation, gas detection and isolation of GH2 storage 7.1.23.9

(2) The fire barrier walls of the HEE shall be without openings.

(a) sealed fire-rated penetrations are permitted.

(3) Fire barrier walls of the HEE shall have a minimum fire resistance rating of not less than 2 hours.

(4) The fire barrier walls of the HEE shall interrupt the line of sight between the hydrogen compressed gas system and the

exposure.


In many ways the distance to exposures can be removed by the used of an HEE as the storage or compressor system is now “contained” by the structure of the HEE and no longer “outdoors”

The containment of compressed storage and compressor systems inside a 4 walled HEE is much different than “outdoor” storage as leaks can be detected and managed by the HEE control systems.

the use of HEE with sealed fire resistant walls is not the same as a fire wall, therefore it is not appropriate to include HEEs in 7.3.2.3.1.2 Reduction of Distance by Mitigation Means section (A) as is proposed in PI 276




Affilliation: BoydH2 in behalf of Linde, LLC

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with 7.3.2.4 . [ this section] . [55:10.4.3.1]


Section refers to itself.




Affilliation: FCHEA

Street Address:

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with 7.3.2.4 . [ 55: 10.4.3.1] be addressed as follows


7.3.2.4 sending to 7.3.2.4 (itself)




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Pressure [GH2] containers installed underground using burial methods shall be of seamless construction in accordance with Part UF or Appendix 22 of the

ASME Boiler and Pressure Vessel Code, Section VIII, Division 1. [ 55: 10.4.3.1.1] .


The specificity of this requirement is unnecessarily restrictive. The data coming out of recent Sandia and NIST analysis indicate welding of current generation materials (uniform microstructure) to be acceptable after thousands of load cycles. Does data exists to show that UNS 4130 forgings are suitable for thousands of load cycles?




Affilliation: FCHEA

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7.3.2.4.3* Outlet Connections.

7.3.2.4.3.1

Threaded Non-tapered threaded [GH2] container outlet connections shall be designed with primary and secondary seals that shall be tested for

functionality. [ 55: 10.4.3.1.4.1]

7.3.2.4.3.2

The seal design non-tapered threaded design shall include a method of detecting a leak in the primary seal. [ 55: 10.

7.3.2. 4.3.

1.4.2]3 Tapered threaded joints shall be avoided for storage pressures exceeding 250 psig.


Sealing with tapered pipe threads, especially at higher pressures, becomes problematic. The seal is a caulk or film located between thread teeth for only a short portion of the thread engagement.

It is suggested that it would be wise to separate requirements between tapered and non-tapered threaded joints. Additionally, seal welding tapered threaded joints is often recommended by industry




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7.3.2.4.3.1

* Threaded [GH2] container outlet connections shall be designed with primary and secondary seals that shall be tested for functionality. [55:10.4.3.1.4.1]

A 7.3.2.4.3.1: Tapered threaded joints shall be avoided for storage pressures exceeding 250 psig.


As fittings and vessels use tapered threads, it was suggested by the FCHEA Hydrogen Codes Task Force Writing Team to develop an annex note on best practice information for safety, rather than proposing a change in requirements. We are open to alternate ways to address the concern.

Sealing with tapered pipe threads, especially at higher pressures, becomes problematic. The seal is a caulk or film located between thread teeth for only a short portion of the thread engagement.

It is suggested that it would be wise to separate requirements between tapered and non-tapered threaded joints. Additionally, seal welding tapered threaded joints is often recommended by industry.




Affilliation: FCHEA

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7.3.2.4.4.1

Joints in the piping system shall be installed and inspected in accordance with the requirements of ASME B31.12, Hydrogen Piping andPipelines B31 Code for Pressure Piping , or other approved standards. [55:10.4.3.1.5.1]


ASME B31.1, B31.3, B31.8 could also be used. The owners would prefer to follow a single section not multiple sections of the code for a site.




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7.3.2.4.6 Foundations.



7.3.2.4.6.1

The concrete foundation shall extend a minimum of 1 ft (0.3 m) horizontally beyond the footprint of the tank in all directions. [ 55: 10.4.3.1.7.1] directions or as stipulated in the locally adopted building code.


Where did the requirement that the foundation be concrete come from? Are we going to get into what type of concrete? This is a regional requirement based on water table and freeze line. Leave foundations to the building code.




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DELETE INERT OR DEFINE IN THIS CONTEXT - WHAT IS DIFFERENCE BETWEEN INERT AND NON-CORROSIVE TO A METAL?




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7.3.2.4.7.1

Containers shall be buried such that the top of the container is covered with a minimum of 1 ft (0.3 m) of earth and then capped with concrete a minimumof 4 in. (101 mm) thick placed over the earthen cover. [ 55: 10.4.3.1.8] a non-flammable, static minimizing building material that complies with the locallyadopted building code. The earthen layer shall be a minimum of 1 ft (0.3 m). The cap shall add an additional 4 in. (100 mm). Unless otherwise stipulatedby the locally adopted building code.


Is this 4” from tank to grade (concrete), 12” from tank to grade (dirt) or 16” from tank to grade (dirt & concrete)? Why would it be necessary to cover with concrete? Why wouldn't the locally adopted building code trump this requirement?




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7.3.4.2.1

Personnel conducting Only personnel authorized by the bulk suppliers shall conduct transfer operations from the a bulk transport vehicle shall betrained .


What does “trained” mean? Who is certified to “train”? Etc. Let’s leave this with the bulk supplier. He has the legal liability during a transfer incident.




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Public Input No. 419-NFPA 2-2016 [ Section No. 8.1 [Excluding any Sub-Sections] ]

The storage, use, and handling of LH 2 in LH 2 storage systems shall of liquefied hydrogen (LH2) shall comply with this chapter in addition to other

applicable requirements of this code.


Define the acronym to save the reader from searching for it




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8.1.2* Containers — Design, Construction, and Maintenance.

Containers employed for the storage or use of [LH 2 ] hydrogen shall be designed, fabricated, tested, marked (stamped), and maintained in accordance

with DOT regulations; Transport Canada (TC), Transportation of Dangerous Goods Regulations; the ASME Boiler and Pressure Vessel Code, “Rules forthe Construction of Unfired Pressure Vessels” ; or regulations of other administering agencies. [55:8.2]


This is the LH2 chapter. Reads better as ‘hydrogen’.Why am I limited to Section VIII? What about Section X or in some cases XII?




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Piping, tubing, fittings, and related components shall be designed, fabricated, and tested in accordance with the requirements of ASME B31 .12, HydrogenPiping and Pipelines Piping Code , or other approved standards and shall be in accordance with 8.1.3.1.1.

8.1.3.1.1 Piping and Appurtenances.

8.1.3.1.1.1

Piping systems shall be designed for the use intended through the full range of pressure and temperature to which they will be subjected. [55:8.14.2.1]

8.1.3.1.1.2

Piping or tubing used at operating temperatures below –20°F (–29°C) shall be fabricated from materials meeting the impact test requirements of ASME B31.12, Hydrogen Piping and Pipelines Piping Code . [55:11.2.3.2]

8.1.3.1.1.3

Piping systems shall be designed and constructed to allow for expansion, contraction, vibration, settlement, and fire exposure. [55:8.14.2.2]

8.1.3.1.2 Joints.

Joints in piping and tubing shall be in accordance with the requirements of ASME B31 .12, Hydrogen Piping and Pipelines Piping Code . [55:11.2.3.3]

8.1.3.1.2.1

Brazing materials, where used, shall have a melting point above 1000°F (538°C). [11:2.3.4]

8.1.3.1.3 Valves and Accessory Equipment.

Valves and accessory equipment shall be acceptable for the intended use at the temperatures of the application and shall be designed and constructed towithstand the maximum pressure at the minimum temperature to which they will be subjected. [55:8.14.4]

8.1.3.1.4 Shutoff Valves on Containers.

Shutoff valves shall be provided on all container connections, except for pressure relief devices. [55:8.14.5]

8.1.3.1.4.1

Shutoff valves for containers with multiple pressure relief devices shall be permitted in accordance with 8.1.4.7. [55:8.14.5.1]

8.1.3.1.4.2

Shutoff valves shall be accessible and located as close as practical to the container. [55:8.14.5.2]

8.1.3.1.5 Shutoff Valves on Piping.

8.1.3.1.5.1

Shutoff valves shall be installed in piping containing [LH2] where needed to limit the volume of liquid discharged in the event of piping or equipment failure.

[55:8.14.6.1]

8.1.3.1.5.2*

Pressure relief valves shall be installed where liquid or cold gas can be trapped between shutoff valves in the piping system. (See 8.1.4 .) [55:8.14.6.2]

8.1.3.1.6 Physical Protection and Support.

8.1.3.1.6.1

Aboveground piping systems shall be supported and protected from physical damage. [55:8.14.7.1]

8.1.3.1.6.2

Piping passing through walls shall be protected from mechanical damage. [55:8.14.7.2]


8.1.3.1.7.1

Aboveground piping that is subject to corrosion shall be protected against corrosion. [55:8.14.8.1]

8.1.3.1.7.2

Belowground piping shall be protected against corrosion. [55:8.14.8.2]

8.1.3.1.8 Cathodic Protection.

Where required, cathodic protection shall be in accordance with 8.1.3.1.8. [55:8.14.9]

8.1.3.1.8.1 Operation.


8.1.3.1.8.2 Inspection.

(A)

Container systems equipped with cathodic protection shall be inspected for the intended operation by a cathodic protection tester. [55:8.14.9.2.1]

(B)


8.1.3.1.8.3 Impressed Current Systems.

(A)

Systems equipped with impressed current cathodic protection systems shall be inspected in accordance with the requirements of the design and8.1.3.1.8.2. [55:8.14.9.3.1]

(B)

The design limits shall be available to the AHJ upon request. [55:8.14.9.3.2]


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(C)




[55:8.14.9.3.3]

8.1.3.1.8.4 Corrosion Expert.

(A)


(B)


8.1.3.1.9 Testing.

8.1.3.1.9.1

Piping systems shall be tested and proved free of leaks after installation as required by the codes and standards to which they are designed andconstructed. [55:8.14.10.1]

8.1.3.1.9.2

Test pressures shall not be less than 150 percent of the maximum allowable working pressure when hydraulic testing is conducted or 110 percent whentesting is conducted pneumatically. [55:8.14.10.2]


Cryogenic systems are actually embedded in ASME B31.3.Chapter 8 is liquid hydrogen, so B31.3 is more applicable.




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Piping, tubing, fittings, and related components shall be designed, fabricated, and tested in accordance with the requirements of of ASME B31 .12,Hydrogen Piping and Pipelines , or Code for Pressure Piping, or other approved standards and shall be in accordance with 8.1.3.1.1 .

8.1.3.1.1 Piping and Appurtenances.

8.1.3.1.1.1

Piping systems shall be designed for the use intended through the full range of pressure and temperature to which they will be subjected. [55:8.14.2.1]

8.1.3.1.1.2

Piping or tubing used at operating temperatures below –20°F (–29°C) shall be fabricated from materials meeting the impact test requirements of ASMEB31.12, Hydrogen Piping and Pipelines . [ 55: 11.2.3.2] A SME B31 Code for Pressure Piping

8.1.3.1.1.3


8.1.3.1.2 Joints.

Joints in piping and tubing shall be in accordance with the requirements of of ASME B31 .12, Hydrogen Piping and Pipelines . [ 55: 11.2.3.3] Code forPressure Piping

8.1.3.1.2.1

Brazing materials, where used, shall have a melting point above 1000°F (538°C). [11:2.3.4]

8.1.3.1.3 Valves and Accessory Equipment.

Valves and accessory equipment shall be acceptable for the intended use at the temperatures of the application and shall be designed and constructed towithstand the maximum pressure at the minimum temperature to which they will be subjected. [55:8.14.4]

8.1.3.1.4 Shutoff Valves on Containers.

Shutoff valves shall be provided on all container connections, except for pressure relief devices. [55:8.14.5]

8.1.3.1.4.1

Shutoff valves for containers with multiple pressure relief devices shall be permitted in accordance with 8.1.4.7. [55:8.14.5.1]

8.1.3.1.4.2

Shutoff valves shall be accessible and located as close as practical to the container. [55:8.14.5.2]

8.1.3.1.5 Shutoff Valves on Piping.

8.1.3.1.5.1

Shutoff valves shall be installed in piping containing [LH2] where needed to limit the volume of liquid discharged in the event of piping or equipment failure.

[55:8.14.6.1]

8.1.3.1.5.2*

Pressure relief valves shall be installed where liquid or cold gas can be trapped between shutoff valves in the piping system. (See 8.1.4 .) [55:8.14.6.2]

8.1.3.1.6 Physical Protection and Support.

8.1.3.1.6.1

Aboveground piping systems shall be supported and protected from physical damage. [55:8.14.7.1]

8.1.3.1.6.2

Piping passing through walls shall be protected from mechanical damage. [55:8.14.7.2]


8.1.3.1.7.1

Aboveground piping that is subject to corrosion shall be protected against corrosion. [55:8.14.8.1]

8.1.3.1.7.2

Belowground piping shall be protected against corrosion. [55:8.14.8.2]

8.1.3.1.8 Cathodic Protection.

Where required, cathodic protection shall be in accordance with 8.1.3.1.8. [55:8.14.9]

8.1.3.1.8.1 Operation.



(A)

Container systems equipped with cathodic protection shall be inspected for the intended operation by a cathodic protection tester. [55:8.14.9.2.1]

(B)



(A)

Systems equipped with impressed current cathodic protection systems shall be inspected in accordance with the requirements of the design and8.1.3.1.8.2. [55:8.14.9.3.1]


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(B)

The design limits shall be available to the AHJ upon request. [55:8.14.9.3.2]

(C)




[55:8.14.9.3.3]

8.1.3.1.8.4 Corrosion Expert.

(A)


(B)


8.1.3.1.9 Testing.

8.1.3.1.9.1

Piping systems shall be tested and proved free of leaks after installation as required by the codes and standards to which they are designed andconstructed. [55:8.14.10.1]

8.1.3.1.9.2

Test pressures shall not be less than 150 percent of the maximum allowable working pressure when hydraulic testing is conducted or 110 percent whentesting is conducted pneumatically. [55:8.14.10.2]


Blanket change to refer to the whole code.




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8.1.3.1.1.2

Piping or tubing used at operating temperatures below –20°F (–29°C) shall be fabricated from materials meeting the impact test requirements of of ASMEB31 .12, Hydrogen Piping and Pipelines . [ 55: 11.2.3.2] Code for Pressure Piping


Blanket change




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8.1.3.1.2.1

Brazing materials, where used, shall have a melting point above 1000°F 840°F (538°C 450°C ). [11:2.3.4]


AWS deines a braze as above 840 f> The braze rod selected will be based on compatibility with the alloys to be brazed, not the liquidus temperature.




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8.1.4.1.1

Pressure relief devices shall be provided to protect containers and systems containing [LH 2 ] from rupture in the event of overpressure.

[ 55: 8.2.4.1.1] containingpiping systems containing hydrogen from damage due to an overpressure.


Leak and deformation are not rupture. Rupture is a catastrophic event. We are also concerned about any loss of containment or any damage which may lead to a catastrophic event.




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8.1.4.1.2

Pressure relief devices shall be designed in accordance with CGA S-1.1, Pressure Relief Device Standards — Part 1 — Cylinders for Compressed Gases,and CGA S-1.2, Pressure Relief Device Standards — Part 2 — Cargo and Portable Tanks for Compressed Gases, for portable tanks; and CGA S-1.3,Pressure Relief Device Standards — Part 3 — Stationary Storage Containers for Compressed Gases, for stationary tanks. [55:8.2.4.1.2]


Why are the only CGA S-1 relief valves allowed? Why aren’t ASME relief valves allowed? Aren’t CGA S-1 relief valves thermally activated?




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Portable containers that are open to the atmosphere and are designed to contain [LH2] at atmospheric pressure shall not be required to be equipped with

pressure relief devices. [55:8.2.4.2]

Boil off from such containers is to be evacuated outdoors (or approved hood) is an accepted manner.


This isn’t nitrogen or air where the Dewar bottle vents boil-off into the room. How is the boil-off issue addressed? This is a flammable gas.

Does the area using the Dewar need to be classified?




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8.1.4.2.2

Containers located indoors shall be within a zone of local exhaust using a mechanical exhaust system.

8.1.4.2.2.1

The exhaust system shall operate continuously when LH2 is present and shall be designed in accordance with the mechanical code for the removal of

flammable vapors.

8.1.4.2.2.2

The duct system used to exhaust the hydrogen released from open containers shall be considered to be a hazardous exhaust system.


8.1.4.2.2 Does the area using the Dewar need to be classified? Why not?

8.1.4.2.2.1 What is an open container. A Dewer is a vacuum flask with a boil off vent. not a cooler with a block of dry ice.

Use the term Dewer and right the clauses for Dewers.




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8.1.6.1.1.1

Portable [LH2] containers shall be marked in accordance with CGA C-7, Guide to the Preparation of Precautionary Labeling and Marking of Compressed

Gas Containers. [55:8.4.1.1.1]


Does CGA C-7 conform to OHSA (HMIS) or NFPA 704? Does NFPA want three different labeling schemes?




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8.1.6.4.1.2

They shall be identified by a schematic drawing that indicates their function and designates whether they are connected to the vapor or liquid space of thecontainer. [55:8.4.4.1.2]

(A) When a schematic drawing is provided, it shall be attached to the container and maintained in a legible condition. [ 55: 8.4.4.1.2.1]

(B) A copy of the schematic shall be included with the application operations and maintenance instructions


A copy should be with the site O&M and possibly LOTO instructions




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8.1.9.1 General.

Electrical wiring and equipment shall be in accordance with NFPA 70, NFPA 79 and 8.1.9. [55:8.8.1]


Why isn’t NPFA 79 referenced? My experience is that NFPA 70 applies between components and the grid. NFPA 79 applies within systems and modules (e.g. – what if you have five 110 circuits in the same box? What are the color code and labeling requirements?




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8.1.14 Emergency Shutoff Valves.

8.1.14.1

Accessible manual or automatic emergency Emergency shutoff valves shall be provided to shut off the LH2 supply in case of emergency.

8.1.14.1.1

Emergency shutoff valves on a bulk source or piping systems serving the bulk supply shall be identified by means of a sign for the first responders .

8.1.14.1.2

Emergency shutoff valves shall be located at the point of use, at the source of supply, and at the point where the system piping enters the building astructure ..


Suggest revising definitions slightly and then referencing definition. The requirements for a fire valve are different from a process valve.

3.3.241.1 Emergency Shutoff Valve. A designated valve designed to shut off the flow of gases or liquids. [55, 2016]

3.3.241.1.1 Automatic Emergency Shutoff Valve. A designated fail-safe automatic closing valve designed to shut off the flow of gases or liquids that is initiated by a control system where the control system is activated by either manual or automatic means. [55, 2016]

3.3.241.1.2 Manual Emergency Shutoff Valve. A manually initiated valve designed to be tamper resistant and intended to be used in an area accessible by the general public to shut off the flow of gases or liquids.

3.3.241.2 Shutoff Valve. A shutoff valve is a valve used to secure the flow of gases or liquids in an areas that are not accessible by the general public.

3.3.241.2.1* Safety Shutoff Valve. A normally closed valve installed in the piping that closes automatically to shut off the fuel, atmosphere gas, or oxygen in the event of abnormal conditions or during shutdown. [86, 2015]

3.3.241.3* Source Valve. A shutoff valve on the piping system serving a bulk gas supply system where the gas supply, at service pressure, first enters the supply line. [55, 2016]




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8.1.15 Dispensing Areas.

Dispensing of [LH2] associated with physical or health hazards shall be conducted in approved locations. [55:8.14.11.3.2]

8.1.15.1 Outdoor Dispensing Areas – reserved.

8.1.15.2 Indoor Dispensing Areas.

Dispensing indoors shall be conducted in areas constructed in accordance with the [adopted] building code. [55:8.14.11.3.2.1]

8.1.15.2 Ventilation .1 Indoor Ventilation for dispensing areas .

Indoor areas in which [LH2] are dispensed shall be ventilated in accordance with the requirements of Section 6.17 and the [adopted] mechanical code.

[55:8.14.11.3.2.2]


Piping systems utilized for filling or dispensing of [LH2] shall be designed and constructed in accordance with 8.1.3.1.1. [55:8.14.11.3.2.3]


Where is Outdoor dispensing areas addressed? This could be inserted as “8.1.15.1 Outdoor Dispensing Areas – reserved”.

8.1.15.2 becomes 8.1.15.2.18.1.15.1 becomes 8.1.15.2.




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Indoor areas in which [LH2] are dispensed shall be ventilated in accordance with the requirements of Section 6.17 and the [adopted] mechanical code .

[ 55: 8.14.11.3.2.2]












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8.2.2.2.4 Installation of LH2 Inside Buildings Other Than Detached Buildings and Gas Rooms.

Portable LH2 containers of 39.7 gal (150 L) or less capacity where housed inside buildings, not located in a gas room, and exposed to other occupancies

shall comply with the following minimum requirements:

(1) Containers shall be located 20 ft (6.1 m) from all classes of flammable or combustible liquids and combustible materials such as excelsior or paper.

(2) Containers shall be located 25 ft (7.6 m) from ordinary electrical equipment and other sources of ignition, including process or analytical equipment.

(3) Containers shall be located 50 ft (15 m) from intakes for ventilation, air-conditioning equipment, or compressors.

(4) Containers shall be located 50 ft (15 m) from the storage or use of other flammable gases or the storage or use of incompatible gases.

(5) Containers shall be protected against physical damage in accordance with the requirements of 8.1.7.5.

(6) Containers shall be secured in accordance with the requirements of 8.1.7.3.

(7) Welding or cutting operations and smoking shall be prohibited while hydrogen is in the room, and signs shall be provided as required by 4.13.3.

(8) Ventilation shall be provided in accordance with the requirements of Section 6.17.

(9) Pressure-relief devices on stationary or portable containers shall be vented directly outdoors or to an exhaust hood. (See 8.1.4.6 )

[55:11.3.3]


bullet (4) Separation distances are most likely excessive. Boil-off is typically a low volumetric flow, low velocity flow event. Suggest basing the distances based on the typical boil-off rate unless the boil-off is plumbed outside. Additionally, the boil-off distances should be reduced outdoors also. The “Thermos bottle” design of a Dewar should protect the Dewar from a structure fire by thermally limiting the amount of boil-off. This should be calculable. I’d expect something on the 2 to 3 times the boil-off rate at room temperature. A 2.5 safety factor on the typical boil off rate would be a defensible position. The average structure fire is ~1100 F.

Bullet (7) (5) Welding or cutting operations and smoking shall be prohibited while hydrogen is allowed to vent into the area, and signs shall be provided as required by 4.13.3.




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Storage and use of [LH2] shall not be located within 50 ft (15.2 m) of air intakes. [55:7.6.2.4]


50 feet sounds excessive for boil-off during a fire. Is this to protect from boil-off or a BLEV event? If boil-off the flow velocity would be about 5 times that of the typical boil-off velocity. %0 ft is excessive for a Dewer..




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Storage and use of [LH2] outside of buildings shall also be separated from building openings by 25 ft (7.6 m). Fire barriers shall be permitted to be used as



see previous comment




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8.2.2.3.5.2

Where exit access is provided to serve areas in which equipment is installed, the minimum width shall be not less than 28 in. (710 mm). [55:8.13.2.2.1]


What does the building code (NFPA 101) require for minimum egress door size?




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8.2.2.3.9.4 Grade.

(A)

The

gradeelevation differential for a distance of not less than

50 ft50 ft (15.

2 m2 m ) from where [

LH 2LH2 ] storage or delivery systems are installed shall be

higher than the grade on whichsuch that a release will not flow into an area where other flammable or combustible liquids are stored or used.

[ 55: 8.13.2.6.4]

(B)*

Drainage Control.

(1) When the grade elevation differential between the storage or delivery system and the flammable or combustible liquids storage or use area is not inaccordance with 8.2.2.3.9.4(A) , diversion curbs or other means of drainage control shall be used to divert the flow of flammable or combustible liquidsaway from the [LH2] system. [55:8.13.2.6.4.1(A)]

(2) The means of drainage control shall prevent the flow of flammable or combustible liquid to a distance not less than 50 ft (15.2 m) from all parts of thedelivery system. [55:8.13.2.6.4.1(B)]


Actually, the term “grade” is a poor choice. It means average change in elevation.




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8.2.3.1.1.1 Operating Instructions.

Operating instructions shall be provided for installations that require the operation of equipment. [ 55: 8.14.1.1] Format and symbology used shallconform to NEMA Z535.


OSHA requirement




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8.2.3.1.1.2 Attended Delivery.

A qualified person shall be in attendance at all times [LH2] is transferred from mobile supply units to a storage system. [55:8.14.1.2]


What makes a person qualified? Are they personnel trained in the process of transferring cryogenic fluids and recognized as such by the owner and the LH2 supplier?

Look at the suggestion for bulk delivery




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(A)

[LH 2 ] storage systems shall be inspected and maintained by a qualified representative of the equipment owner [-]. [ 55: 8.14.1.4.1]

(1) The interval between inspections [-] shall be based on nationally recognized good practices or standards. [ 55: 8.14.1.4.1.1] local regulation, or lackingregulation, the safety analyses

(2) A record of the inspection history shall be

prepared and provided

(3) maintained by the owner and shall be available to the

user or the

(4) authority having jurisdiction upon request.

[ 55: 8.14.1.4.2]

(5)


In ASME speak, you inspect paperwork and examine hardware. The skill sets being different. What is it in NFPA speak?

Proposed changes add clarity.




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(A)

[LH2] storage systems shall be inspected and maintained by a qualified representative of the equipment owner [-]. [55:8.14.1.4.1]

(1) The interval between inspections [-] shall be based on nationally recognized good practices or standards. [55:8.14.1.4.1.1]

(2) A record of the inspection shall be prepared and provided to the user or the authority having jurisdiction upon request. [55:8.14.1.4.2]


Editorial.




Affilliation: FCHEA

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8.2.3.1.2.2



Fire exposure? Are we insulating the pipes? With the exception of fire exposure this is redundant with calling out the piping code.




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(A) Container systems equipped with cathodic protection shall be

inspected

examined for the intended operation by a cathodic protection tester.

[ 55: 8.14.9.2.1]

(B)

The examinations shall be documented.

(C) A record of the examination history shall be maintained by the owner and shall be available to the authority having jurisdiction upon request

(D) The cathodic protection tester shall be certified as being qualified by the National Association of Corrosion Engineers, International (NACE).

[ 55: 8.14.9.2.2]


In ASME speak, you inspect paperwork and examine hardware. The skill sets being different. What is it in NFPA speak?

Incomplete requirement?




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(A) Systems equipped with impressed current cathodic protection systems shall be

inspected in accordance with the requirements of the design and 8.2.3.1.9.2 . [ 55: 8.14.9.3.1]

i

examined for the intended operation by a qualified examiner. The examinations shall be documented

(B) The design limits shall be available to the AHJ upon request. [ 55: 8.14.9.3.2]

(C) The system owner shall maintain the following records to demonstrate that the cathodic protection is in conformance with the requirements of thedesign:

(1) The results of inspections of the examinationof the system

(2) The

results of testing that has been completed

[ 55: 8.14.9.3.3]

(1) report indicating that the impressed current system is operating properly and that the corrosion of the hardware being protected has not exceededsafety margins.


Incomplete requirement?




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8.2.3.1.9.5


(A)



What is the “A” for?




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(A)



Editorial - does not apply to source document.




Affilliation: FCHEA

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8.2.3.2.1.1 General.

A qualified person shall be in attendance at all times [LH 2 ] is transferred from mobile supply units to a storage system. [ 55: 8.14.1.2]


This is redundant to section 8.2.3.1.1.2. and 8.3.3.1.4. Requesting the TC consider either cleaning this up by removing one or more occurrences, or perhaps placing the requirement in Section 8.1. Is there ever a case in NFPA 2 where a qualified person need not be in attendance when [LH2] is transferred from mobile supply units to a storage system?



Public Input No. 204-NFPA 2-2016 [Section No. 8.3.3.1.4 [Excluding any Sub-Sections]] redundancy issue




Affilliation: FCHEA

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8.2.3.2.1.1 General.

A qualified person shall be in attendance at all times [LH2] is transferred from mobile supply units to a storage system. [55:8.14.1.2]


See Comments for 8.2.3.1.1.2




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8.2.3.2.1.3 Ventilation.

Indoor areas in which [LH2 is] dispensed shall be ventilated in accordance with the requirements of Section 6.17 and the [adopted mechanical code] .

[55: 8.14.11.3.2.2 ]












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8.2.4.4.1

Pressurized containers shall be closed while transported. [55:8.14.11.4.4.1]


We need a better word than closed. Closed can be misconstrued. Sealed? Container valve closed?




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8.3.1.2.3* Piping, Tubing, and Fittings.

8.3.1.2.3.1

Piping and tubing shall be in accordance with the requirements of of ASME B31 .12, Hydrogen Piping and Pipelines . [ 55: 11.2.3.1] Code for PressurePiping

8.3.1.2.3.2*

Piping or tubing used at operating temperatures below −20°F (−29°C) shall be fabricated from materials meeting the impact test requirements of Chapter IIIof of ASME B31 .12, Hydrogen Piping and Pipelines . [ 55: 11.2.3.2] Code for Pressure Piping

8.3.1.2.3.3

Piping and tubing materials that have a minimum design metal temperature (MDMT) or −425°F (254°C) or lower, as defined and specified in in ASME B31.12, Hydrogen Piping and Pipelines, shall Code for Pressure Piping shall be permitted to be used without used without impact testing. [ 55:11.2.3.2.1]

8.3.1.2.3.4

Piping and tubing materials that have a MDMT greater than −425°F (−254°C) shall be permitted to be used after impact testing has been performed and thematerials have passed. [55:11.2.3.3.2]

8.3.1.2.3.5

Joints in piping and tubing shall be in accordance with the requirements of of ASME B31 .12, Hydrogen Piping and Pipelines . [ 55: 11.2.3.3] Code forPressure Piping

8.3.1.2.3.6

Brazing materials, where used, shall have a melting point above 1000°F (538°C). [55:11.2.3.4]

8.3.1.2.3.7

Aluminum piping systems and components external to the storage vessel shall not be used with LH2 except for ambient air vaporizers. [55:11.2.3.5]

8.3.1.2.3.8*

Means shall be provided to minimize exposure of personnel to piping operating at low temperatures and to prevent air condensate from contacting piping,structural members, and surfaces not designed for [LH2] temperatures. [55:11.2.3.6]

(A)

Insulation on piping systems used to convey [LH2] shall be of noncombustible material and shall be designed to have a vaportight seal in the outer covering

to prevent the condensation of air and subsequent oxygen enrichment within the insulation. [55:11.2.3.6.1]

(B)

The insulation material and outside shield shall be designed to prevent deterioration of the insulation due to normal operating conditions. [55:11.2.3.6.2]

8.3.1.2.3.9

Uninsulated piping and equipment that operates at LH2 temperatures shall not be installed above asphalt or other combustible materials or surfaces in

order to prevent the contact of liquid air with such materials. [55:11.2.3.7]

8.3.1.2.3.10

Drip pans shall be allowed to be installed under uninsulated piping and equipment to retain and vaporize condensed liquid air. [55:11.2.3.8]

8.3.1.2.3.11

Cleaning and purging of piping systems shall be in accordance with Section 6.21.


The ASME code will guide you. The requirements are the same for the various sections. Currently Section 3 has cryo-systems




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8.3.1.2.3.6

Brazing materials, where used, shall have a melting point above 1000°F 840°F (538°C 450°C ). [55:11.2.3.4]


AWS defines a braze as above 840 F




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8.3.1.2.3.9

Uninsulated piping and equipment that operates at LH2 temperatures shall not be installed above asphalt or other combustible materials or surfaces in

order to prevent the contact of liquid air with such materials. [55:11.2.3.7]

Hardware and piping accessible to the general public shall be guarded to protect the general public from the low temperature surfaces


Very cold pipes, hot humid day and people - bad combination.




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8.3.1.2.3.10

Drip pans shall be allowed to be installed under uninsulated piping and equipment to retain and vaporize condensed liquid air. [55:11.2.3.8] The drip panshall be of minimum size and planform to prevent standing water resulting in breeding places for insects.


With all the mosquito issues, limiting the drip pans before the board of health steps in might be wise.




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8.3.1.2.4.2

Storage containers, piping, valves, regulating equipment, and other accessories shall be accessible and shall be protected against physical damage andtampering. [55:11.2.4.2]

(A)

Emergency shutoff valves shall be located in liquid and vapor use lines as close to the container as practical to terminate all flow to use lines during anemergency. [55:11.2.4.2.1]

(B)

Containers exceeding 2000 gal (7570 L) capacity shall be provided with an automatic emergency shutoff valve. [55:11.2.4.2.2]

(1) The remotely operated emergency isolation valve shall be operated by a remotely located, manually activated shutdown control. [55:11.2.4.2.2.1]

(2) The shutoff valve shall be connected to the primary container by means of welded connections without the use of flanges or other appurtenancesexcept that a manual shutoff valve equipped with welded connections is allowed to be installed immediately upstream of the automatic shutoff valve toallow for maintenance of the automatic valve. [55:11.2.4.2.2.2]

(3) Connections downstream of the shutoff valve shall be in accordance with with ASME B31 .12 Hydrogen Piping and Pipelines . Code for PressurePiping [ 55: 11.2.4.2.2.3]


The code will direct. This is a blanket issue




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8.3.1.2.8.1 Valve Isolation.

(A)

Valves shall be installed such that each pump or compressor can be isolated for maintenance. [55:11.2.8.1.1]

(B)

Where pumps or compressors are installed for operation in parallel, each discharge line shall be equipped with a check valve to prevent the backflow ofliquid from one system to the other. [55:11.2.8.1.2]


Require a function not hardware.




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8.3.1.2.8.5* Pressure Monitoring.

(a) The pressure on the pump or compressor discharge shall be monitored by a control system. [55:11.2.8.5]

(A b ) Discharge pressures in excess of the equipment design pressures shall cause the pump or compressor to shut down. [ 55: 11.2.8.5.1]


the (A) was dangling and needed company




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8.3.2.1.2*

Diking shall not be used to contain a LH 2 spill. [ 55: 11.3.1.2] Pooling of a release is prohibited. The use of berms or dykes may be used to redirect flow

from an additional hazard.


Dykes are a tool. The function is to prevent pooling. A dyke or berm may be required to separate hazards.




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8.3.2.1.4 Aboveground Tanks.

Aboveground tanks for the storage of [LH2] shall be in accordance with 8.3.2.1.4. [55:8.2.1]

8.3.2.1.4.1 Construction of the Inner Vessel.

The inner vessel of storage tanks in [LH2] service shall be designed and constructed in accordance with Section VIII, Division 1 of the ASME Boiler and

Pressure Vessel Code and shall be vacuum jacketed in accordance with 8.3.2.1.4.2. [55:8.2.1.1]

8.3.2.1.4.2 Construction of the Vacuum Jacket (Outer Vessel).

(A)

The vacuum jacket used as an outer vessel for storage tanks in [LH2] service shall be of welded steel construction designed to withstand the maximum

internal and external pressure to which it will be subjected under operating conditions to include conditions of emergency pressure relief of the annularspace between the inner and outer vessel. [55:8.2.1.2.1]

(B)

The jacket shall be designed to withstand a minimum collapsing pressure differential of 30 psi (207 kPa). [55:8.2.1.2.2]

(C) Vacuum Level Monitoring.

(1) A connection shall be provided on the exterior of the vacuum jacket to allow measurement of the pressure within the annular space between the innerand the outer vessel. [55:8.2.1.2.3.1]

(2) The connection shall be fitted with a bellows-sealed or diaphragm-type valve equipped with a vacuum gauge tube that is shielded to protect againstdamage from impact. [55:8.2.1.2.3.2]

8.3.2.1.4.3 Nonstandard Containers.

(A)

Containers, equipment, and devices that are not in compliance with recognized standards for design and construction shall be permitted if approved by theauthority having jurisdiction upon presentation of evidence that they are designed and constructed for safe operation. [55:8.2.2.1]

(B)

The following data shall be submitted to the authority having jurisdiction with reference to the deviation from the standard with the application for approval:

(1) Type and use of container, equipment, or device

(2) Material to be stored, used, or transported

(3) Description showing dimensions and materials used in construction

(4) Design pressure, maximum operating pressure, and test pressure

(5) Type, size, and setting of pressure relief devices

[55:8.2.2.2]

8.3.2.1.4.4 Foundations and Supports.

Stationary tanks shall be provided with concrete or masonry foundations or structural steel supports on firm concrete or masonry foundations, and therequirements of 8.3.2.1.4.4(A) through 8.3.2.1.4.4(E) also shall apply. [55:8.2.3]

(A) Excessive Loads.

Stationary tanks shall be supported to prevent the concentration of excessive loads on the supporting portion of the shell. [55:8.2.3.1]

(B) Expansion and Contraction.

Foundations for horizontal containers shall be constructed to accommodate expansion and contraction of the container [55:8.2.3.2]

(C)* Support of Ancilliary Equipment.

(1) Foundations shall be provided to support the weight of the vaporizers or heat exchangers. [55:8.2.3.3.1]

(2) Foundations shall be designed to withstand soil and frost conditions as well as the anticipated seismic, snow, wind, and hydrostatic loading underoperating conditions. [55:8.2.3.3.2]

(D) Temperature Effects.

Where drainage systems, terrain, or surfaces beneath stationary tanks are arranged in a manner that can subject stationary tank foundations or supports totemperatures below –130°F (–90°C), the foundations or supports shall be constructed of materials that are capable of withstanding the low-temperatureeffects of [LH2] spillage. [55:8.2.3.4]

(E) Corrosion Protection.

Portions of stationary tanks in contact with foundations or saddles shall be painted to protect against corrosion. [55:8.2.3.5]


Limiting the designer unnecessarily




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Ventilation shall be provided in accordance with the requirements of Section 6.17 and 8 . 3.2.2.2.2(A) through 8.3.2.2.2.2(D) . [55: 11.4.4.2 ]

(A)

Inlet openings shall be located within 18 in. (0.46 m) of the floor in exterior walls only. [ 55: 11.4.4.2.1]

(B)

Outlet openings shall be located at the high point of the room in exterior walls or the roof. [ 55: 11.4.4.2.2]

(C)

Both the inlet and outlet vent openings shall have a minimum total area of 1 ft 2 /1000 scf (1 m 2 /300 Nm 3 ) of room volume. [ 55: 11.4.4.2.3]

(D)

Discharge from outlet openings shall be directed or conducted to a location that allows for dissipation of the exhaust air in the ambient surroundings awayfrom air intakes and occupied spaces. [ 55: 11.4.4.2.4]











Affilliation: Quong & Associates, Inc.,/Toyota USA

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8.3.2.2.2.3* Ignition Sources.

There shall be no sources of ignition within the room or area where the hydrogen system is installed. [55:11.4.4.3]

The room or area where the hydrogen system is located is to be classified as Class 1 Division 1 as defined in NFPA 70 Article 500 through 505.


Is this mandating Class 1 Division 1? If so, why? Why not use Article 500 language?




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8.3.2.3.1.1 Access.

(A)

Stationary containers shall be located to provide access by mobile supply equipment and authorized personnel. [55:8.13.2.2]

(B)

Where exit access is provided to serve areas in which equipment is installed, the minimum width shall be not less than 28 in. (710 mm). [55:8.13.2.2.1]


What does the building code (NFPA 101) require for minimum egress door size? Do we comply?




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8.3.2.3.1.4 Drainage.

(A)

The area surrounding stationary and portable containers shall be provided with a means to prevent accidental discharge of fluids from endangeringpersonnel, containers, equipment, and adjacent structures and from entering enclosed spaces in accordance with [the adopted fire prevention code].[55:8.13.2.6.1]

(B)

The stationary container shall not be placed where spilled or discharged [LH2] will be retained around the container. [55:8.13.2.6.2]

(C)

The provisions of 8.3.2.3.1.4(B) shall be permitted to be altered or waived where the authority having jurisdiction determines that the container does notconstitute a hazard after consideration of special features such as the following:

(1) Crushed rock utilized as a heat sink

(2) Topographical conditions

(3) Nature of occupancy

(4) Proximity to structures on the same or adjacent property

(5) Capacity and construction of containers and character of fluids to be stored

[55:8.13.2.6.3]

(D) Grade.

The grade for a distance of not less than 50 ft (15.2 m) from where cryogenic fluid storage or delivery systems are installed shall be higher than the gradeon which flammable or combustible liquids are stored or used. [55:8.13.2.6.4]

(1) Drainage Control.

(a) Where the grade differential between the storage or delivery system and the flammable or combustible liquids storage or use area is not inaccordance with 8.3.2.3.1.4(D), diversion curbs or other means of drainage control shall be used to divert the flow of flammable or combustibleliquids away from the [LH2]. [55:8.13.2.6.4.1(A)]

(b) The means of drainage control shall prevent the flow of flammable or combustible liquid to a distance not less than 50 ft (15.2 m) from all parts ofthe delivery system. [55:8.13.2.6.4.1(B)]


See comments for 8.2.2.3.9.4




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Public Input No. 303-NFPA 2-2016 [ Section No. 8.3.2.3.1.6(B) ]

(B)

Unloading connections on delivery equipment shall not be positioned closer to any of the exposures cited in Table 8.3.2.3.1.6(A) than the distances givenfor the storage system. [55:11.3.2.3]

(1) The distances in table 8.3.2.3.1.6(A) Group 1 and Group 2 may be reduced to 50 feet when the following active mitigation methods are installed andemployed as standard practice at the bulk liquid hydrogen storage site:

(a) the installed bulk liquid hydrogen system shall include equipment to allow for connection of both liquid transfer (fill) hose and a separate trailer “headspace” vent hose to connect to the bulk storage system vent stack.

(b) all liquid hydrogen delivery trailers shall utilize a vent hose connection method to vent the trailer head space to the bulk storage vent stack system at theend of the bulk liquid hydrogen trans-fill process.

(c) the liquid hydrogen delivery procedures shall incorporate the physical changes required in (a) and (b) above to eliminate “end of trans-fill venting” at thetrailer vent stack.

(d) all liquid hydrogen delivery trailers trans-filling at the site are equipped with an emergency shutdown (ESD) system and fast acting liquid hydrogen shutoff valve that will isolate the trailer in the event of an emergency during the trans-fill process


The existing setback distance required by NFPA section are based on the vent-down of trailer headspace after fueling events happening at the back of the trailer, where there is a relatively low-to-the-ground vent stack on the top of the trailer. By moving the discharge point of the trans-fill related vent release from the back end of the trailer vent to the much taller bulk storage system vent the key drivers for the separation distance from the back of the trailer has been eliminated.

These alternative trans-fill procedures reduce the setback distance requirements from the back of the trailer, and minimize the risks associated with the liquid hydrogen trans-fill process. Based on the supporting information at the time of this submittal, the setback distance from the end of the trailer, the fill connection point and fill connections on the liquid hydrogen trailer shall be a minimum of 50 feet

The Linde North American engineering and risk management teams have reviewed the potential for leaks and has chosen as a worst case a 10% leak area of the liquid transfer hose. Linde engineering standards are based on high pressure oilfield leak data known as the Dutch Purple Book Table and 3.19 to show a likelihood of 4x10^-5.yr for leaks of up to 10% leak area for equipment such as the 1.5" ID Vacuum Jacketed Air Force-type bayonet hose according to the guidelines of Appendix H of NFPA 55.

The need for setback distance from the fill point to be equal to the setback distance of the installed bulk liquid hydrogen tank is no longer necessary with the use of the improved trans-fill procedures which eliminates the need to vent hydrogen from the back end of the trailer at the end of the trans-fill event. The distance to exposures is now driven by the potential leaks in the liquid hydrogen transfer hose, connections and devices on the trailer and the control valves on the bulk liquid hydrogen tank and conservative modeling of those leaks show a worst case leak with a 41 foot range of flammability (based on the conservative 4% LFL and 10 % leak area assumptions)

Linde has implemented PHAST dispersion models to calculate the horizontal distance to the 4% volume fraction concentration (LFL) of hydrogen in air at the 7ft (door height) elevation to be 41 feet. This is a very conservative large leak rate assumption and although the probability of such a leak is extremely low, the horizontal distance such a hydrogen jet could travers in unfavorable wind conditions (same direction as the jet) is 41 feet. NFPA 2 setback distances are currently based on 3% leak area (still very conservative) and Linde PHAST modeling using the of the NFPA 2 shows a horizontal distance of 14.5 feet to the LFL of 4%. If we are to use the assumptions from the NFPA-2 Task Group and the worst case leaks that will be accepted by the NFPA 2 technical committee for the 3rd edition of NFPA 2, for compressed setback distances the assumptions would be 1% leak area and effective LFL for hydrogen in air at 8% and this would justify perhaps a 25 foot setback distance from the back end of the trailer and from the liquid hydrogen fill connection point.

It is possible that Sandia, BoydH2, Linde and other members of the Liquid H2 separations task group may be able to provide further justification to allow for a greater reduction of setback distance to the back end of the trailer than this proposal for changing from 75 to 50 feet .




Affilliation: submitted on behalf of Linde, LLC

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(A) Construction.

Storage tanks for liquid hydrogen shall be designed and constructed in accordance with Section VIII of ASME Boiler and Pressure Vessel Code and shallbe vacuum-jacketed in accordance with 8.3.2.3.1.7(A)(1). [55:11.4.3.1]

(1) Vacuum Jacket Construction.

(2) The vacuum jacket shall be designed and constructed in accordance with

Section VIII of ASME

(a) ASME Boiler and Pressure Vessel Code and shall be designed to withstand the anticipated loading, including loading from vehicular traffic,where applicable. [ 55: 11.4.3.1.1.1]

(b) Portions of the vacuum jacket installed below grade shall be designed to withstand anticipated soil, hydrostatic, and seismic loading.[ 55: 11.4.3.1.1.2]

(c) The vacuum jacket shall be constructed of stainless steel or other approved corrosion-resistant material. [ 55: 11.4.3.1.1.2(A)]

(d) Corrosion Protection. The vacuum jacket shall be protected by an engineered cathodic protection system. A cathodic protection systemmaintenance schedule shall be provided and reconciled by the owner/operator. Exposed components shall be inspected at least twice a year.[ 55: 11.4.3.1.1.2(B)]


Over constraining the designer again.




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8.3.3.1.3 Operating Instructions.

Operating instructions shall be provided for installations that require the operation of equipment. [55:8.14.1.1]






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8.3.3.1.4 Attended Delivery.

A qualified person shall be in attendance at all times [LH2 is] transferred from mobile supply units to a storage system. [55:8.14.1.2]

8.3.3.1.4.1 Cleaning and Purging of Gas Piping Systems.

Cleaning and purging of piping systems shall be in accordance with Section 6.21.


See Comments for 8.2.3.1.1

See 6.21




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A qualified person shall be in attendance at all times [LH 2 is] transferred from mobile supply units to a storage system. [ 55: 8.14.1.2]


This is redundant to section 8.2.3.1.1.2. and 8.3.2.1.1. Requesting the TC consider either cleaning this up by removing one or more occurrences, or perhaps placing the requirement in Section 8.1. Is there ever a case in NFPA 2 where a qualified person need not be in attendance when [LH2] is transferred from mobile supply units to a storage system?







Affilliation: FCHEA

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8.3.3.1.5 Inspection.

8.3.3.1.5.1

[LH2] storage systems shall be inspected and maintained by a qualified representative of the equipment owner[-]. [55:8.14.1.4.1]

(A)

The interval between inspections [-] shall be based on nationally recognized good practices or standards. [55:8.14.1.4.1.1]

8.3.3.1.5.2

A record of the inspection shall be prepared and provided to the user or the authority having jurisdiction upon request. [55:8.14.1.4.2]






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Indoor areas in which [LH2] is dispensed shall be ventilated in accordance with the requirements of Section 6.17 and the [adopted mechanical code] .

[55: 8.14.11.3.2.2 ]












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8.3.4.4.1

Pressurized containers shall be closed while being transported. [55:8.14.11.4.4.1]


What does this mean for a Dewer?




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8.3.4.5.1

Personnel conducting transfer operations from the bulk transport vehicle shall be trained.






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10.2.1.2*

A hazard analysis shall be conducted on every hydrogen fueling system installation by a qualified engineer(s) with proven expertise in hydrogen fuelingsystems, installations, and hazard analysis techniques. Standard designs that have been previously analyzed by recognized methodology do not requirere-analysis each and every time such an installation occurs, only site-specific elements that are unique to the installation shall be reviewed in concert withthe existing analysis performed on the standard system to ensure that the standard design has not been altered in a way that would negatively affect theexisting hazard analysis .


Reason: This proposal takes guidance language from the annex note and places that language within the body of the code to provide specific enforceable language, rather than just guidance to eliminate unnecessary costs for redundant analysis.



Public Input No. 349-NFPA 2-2016 [Section No. A.10.2.1.2]





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10.3.1.1* System Component Qualifications.

The following systems and system components shall be listed or approved:

(1) Pressure relief devices, including pressure relief valves

(2) Pressure gauges

(3) Pressure regulators

(4) Valves

(5) Hose and hose connections

(6) Vehicle fueling connections (nozzle)

(7) Electrical equipment used with GH2 systems

(8) Gas detection equipment and alarms

(9) Hydrogen dispensers

(10) Pressure switches

(11) Flow meters

(12) Breakaway devices

(13) Dispenser enclosure


Items such as pressure relief valves, pressure gauges, valves, etc. are covered under ASME codes (such as BPV, B31.X, ASME B40.100 (for gauges). Why does this standard require these items to be listed when they don't exist and have design standards already present.


Submitter Full Name: Bryan Gordon

Organization: Nuvera Fuel Cells Inc

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Submittal Date: Fri Mar 18 14:28:00 EDT 2016


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(2) Pressure gauges


(4) Valves







(11) Flow meters



(14) Compressor

(15) Fittings


This proposal includes terminology for additional system components for hydrogen dispensing.



Public Input No. 73-NFPA 2-2016 [NewSection after M.1.2.6]

PI #311 adds compressor and fitting system components. PI #73 proposes to add CSA Group standards asReference Publications for these system components.

Public Input No. 68-NFPA 2-2016 [SectionNo. A.10.3.1.1]




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(2) Pressure gauges


(4) Valves

(5)

(6)

(7)

(8)







(15) Flow meters



(18)


ASME PSV’s are not listed or approved. Pressure gauges and transducers are not listed or approved, but ASME suggests conforming to ASME B40.100. Regulators and Valves are not listed or approved. All of these items fall under the ASME piping code.

Equipment is listed, not functions like ‘alarms’.




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Submittal Date: Sat Jun 25 12:40:00 EDT 2016


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10.3.1.2

Devices not otherwise specifically provided for shall be constructed to provide safety equivalent to that required for other parts of a system.


Delete 10.3.1.2 altogether. Non enforceable and doesn’t really say anything useful. Restates what is already regular industry practices.




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Pressure Lifting devices on pressure relief valves for GH 2 GH2 service shall not be accessable by the public. If accessable, they shall not be fitted with

lifting devices.


Why do we limit the use of lifting devices. As long as the lifting devices are not accessible by the operator it should be OK.




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10.3.1.4.1.1

The adjustment, if external, shall be provided with a means for sealing the adjustment to prevent resist tampering.


You can’t make it idiot proof, just idiot resistant.




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10.3.1.4.1.5

Pressure relief valves protecting ASME pressure vessels shall be repaired, adjusted, and tested in accordance with the ASME Boiler and Pressure VesselCode with local regulation .


ASME handles new design and construction. NBBI handles repair and inspection. These rules are in place for the AHJ and he knows them. Hence ' local regulations




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10.3.1.4.2.3*

Pressure relief devices installed on hydrogen dispensers shall exceed the full flow capacity of the dispenser supply.


Where is the full flow of the dispenser measured? This needs to be specified so that the user of this document is informed so that the vehicle is not over pressurized.




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Pressure relief valves shall be tested at least every 5 years. tested as required by local regulation or in accordance with manufacturer's recommendations..


This requirement is set by the NBIC and local regulation. The AHJ already knows how to handle this.




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(B)

Pressure relief devices designed and installed in accordance with 10.3.1.4.1.5 shall be examined and tested in accordance with the applicablerequirements of the ASME Boiler and Pressure Vessel Code local regulation .


AHJ knows these rules.




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Pressure Gauge Design Standards

Pressure gauges shall be per ASME B40.100 or equivalent standards.


Pressure gauges need to be designed per the current and used codes within industry. This ensures the pressure gauges meet specific requirements.




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10.3.1.5.1

A pressure gauge , if provided, and transducers shall be capable of reading at least 1.2 times the system MAWP.


System could have either a gauge or transducer; changing section will ensure either component is rated for the correct pressure.Removed “if provided” because if the system doesn’t have either then the section doesn’t apply but if it has one or the other, then it does.




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10.3.1.5.4 Pressure gauges and transducers shall include provisions to protect from flow induced vibration, provided the protection does not materiallyaffect the response time of the instrument.


A transient flow resulting in large changes in pressure is likely to induce flow induced vibration which may be detrimental to the instrument and the accuracy of the measurement.




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10.3.1.5.3

Pressure gauges and transducers shall be constructed

such that the gauge willin accordance with ASME B40.100 and shall protect personnel under overpressure conditions (e.g., blow-out back or secondary containment andrelease).


ASME B40.100 is the design standard for this hardware.




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10.3.1.6.4

Pressure regulators shall be designed and installed in accordance with ASME B31.X


Pressure regulators have design standards that need to be followed. Granted the standard already refers to all tubing/piping needs to be per ASME B31.X if the document has specific requirements for regulators it should also specify ASME B31.X (or equivalent)




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10.3.1.7.1.1

Piping components in contact with hydrogen Wetted piping, tubing, fittings, gaskets, and packing material shall be compatible with the hydrogen serviceconditions.


Section revised for clarity and to ensure all components are included. This also clarifies that we intended hydrogen and service conditions




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10.3.1.7.1.2

Gray Cast , ductile, and cast malleable or high silicon iron pipe , valves, and fittings shall not be used.


ASME B31.12 does not endorse the use of cast, ductile, malleable or high silicon irons. Refere to ASME B31.12 GR-2.1.4 (b)(1).




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10.3.1.7.3 *

Hydrogen gas piping shall be fabricated and tested in accordance with ANSI/ASME B31.3, Process Piping . X Standards of Pressure Piping


You can use multiple sections of ASME B31.X (power piping, hydrogen piping, b31.3). They all follow similar methods and do the same thing. It's up to the designer to design the system to the appropriate standard where the dispenser will be installed.




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10.3.1.7.3*

Hydrogen gas piping shall be fabricated and tested in accordance with ANSI/ASME B31. 3 12 , Process Hydrogen Piping and Pipelines .


Correlation with the International Fuel Gas Code and consistency within NFPA 2.



Public Input No. 398-NFPA 2-2016 [Section No. 7.1.15.1 [Excluding any Sub-Sections]] Correlation





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10.3.1.7.3*

Hydrogen gas piping shall be fabricated and tested in accordance with ANSI/ with ASME B31 .3, Process Code for Pressure Piping .


ASME B31 consists of over ten sections. Each section is industry specific. However, regardless of the section, you get the same technical answer. ASME does not require a fossil power plant which is built to B31.1 to design a hydrogen line to B31.12. Nor is a refinery built to B31.3 to design a line to B31.12.




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Piping joints made with tapered threaded pipe and sealant shall not be used downstream of the source valve in hydrogen service above 3000 psi (20.7MPa).


Why - what standard is driving this? NPT is perfectly fine to be used in high pressure hydrogen applications as long as it is the correct classification of thread. Autoclave, HIP, Swagelok, BuTECH, etc. all make NPT fittings up to 10 KSI. As long as these are properly installed and correct NPT thread classification they seal




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10.3.1.7.4.2 Seal welds may be used only to prevent leakage of threaded joints and shall not be considered as contributing any strength to the joints. ..


This requirement is spelled out in ASME B31.12; part IP-5.2.2 (d) Seal Welds




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10.3.1.7.4.3 A threaded joint to be seal welded shall be made up without thread compound. A joint containing thread compound that leaks during leaktesting may be seal welded provided all compound is removed from exposed threads.


This is spelled out in ASME B31.12 IP-9.14 (b) Joints for Seal Welding.




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10.3.1.7.4.1

Tapered joints shall be allowed on systems exceeding 3000 psi (20.7 MPa) under the following conditions:

(1) Where valves or instrumentation are not available with straight threads

(2) Where tapered joints are seal welded in accordance with the requirements of ANSI/ASME B31.3, Process Piping .


Again to the reference above - NPT threads are suitable for high pressure hydrogen as long as the correct classification of thread is used.




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10.3.1.7.4.1



(2) Where tapered joints are seal welded in accordance with the requirements of ANSI/ASME B31. 3 12 , Process Hydrogen Piping and Pipelines .


Correlation.



Public Input No. 398-NFPA 2-2016 [Section No. 7.1.15.1 [Excluding any Sub-Sections]]





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10.3.1.7.4.1



(2) Where tapered joints are seal welded in accordance with the requirements of ANSI/ the ASME B31 .3, Process Piping . Code for Pressure Piping


see 10.3.1.7.4.1 - standard reference




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10.3.1.7.6.6

A bend in piping or tubing shall have the pressure rating reduced according to ANSI/ASME B31.3, Process Piping . X - Standard of Pressure Piping


Generalize the use of pressure piping code and allow the designer to apply the appropriate design codes for the application.




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10.3.1.7.6.6

A bend in piping or tubing shall have the pressure rating reduced according to ANSI/ASME ASME B31. 3 12 , Process Hydrogen Piping and Pipelines .


Correlation with NFPA 2 and with International Fuel Gas Code.








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10.3.1.7.6.6

A bend in piping or tubing shall have the pressure rating reduced according to ANSI/ to ASME B31 .3, Process Code for Pressure Piping .


See previous comments - standardized title




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10.3.1.8.3

Prior to use, hose assemblies shall be tested by the component OEM or its designated representative at a pressure at least twice the maximum allowablepressure pressure and marked accordingly as “passed” with “date of test” .


Would verify assemblies were tested. I don’t think “marking” the hoses and assemblies is practical. Perhaps change to “Records of testing shall be maintained”.




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10.3.1.8.4

Hose and metallic hose shall be distinctly marked by the manufacturer, either by the manufacturer’s permanently attached tag or by distinct markingsindicating the manufacturer’s name or trademark, applicable service identifier, and design pressure, and flow direction .


Proposed change was decided on at TG at conference call on 6/13/16. Pipe, tube and hose do not have a flow direction. Components often do.




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10.3.1.8.5

The use of hose in a hydrogen dispensing system shall be limited to vehicle fueling hose

.

10.3. 1 .8.5.1

Each section shall be installed so that it is protected against mechanical damage and accessible for inspection.


Why does this affect the safety of the system? If the dispenser designer wishes to use hoses within the dispenser system for other than vehicle refueling (e.g. in place of tubing, dewatering, etc.) they should be able to do so as long as the hose is designed for hydrogen service, the engineer has performed due diligence to ensure the permeation is OK and the hoses are on an appropriate maintenance schedule to prevent cyclic fatigue.




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10.3.1.8.6.1

Such devices shall be arranged to separate using a force not greater than 150 lb (68 kg) and a minimum of _____ when applied in any direction that thevehicle would move.


There needs to be a minimum value for the break away. I think this information is in existing CSA HGV 4.X documents.




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10.3.1.8.6.1

Such devices shall be arranged to separate using a force not greater than 150 lb lb ( 68 kg 667 N ) when when applied in any direction that the vehiclewould move.


N or Newtons is a force, kg is a mass per ANSI SI-10

Value agrees with “CSA HGV 4.4-2013; 2.4 Separation Test” protocol.




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All system components valves shall be listed or approved designed per ASME B31.X for the hydrogen service pressures, internal and externaltemperatures, and operating environment of the hydrogen dispensing system.


No listed or approved valves exist and the CSA documents are not suitable for use by industry (it makes the valves incredibly costly). Many manufacturers design valves per ASME B31.3 and are perfectly suitable. They have appropriate safety margins built in and a competent engineer will be able to determine material compatibility issues.




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10.3.1.9.1.2

Leakage shall not occur when tested Valve leakage (externally) shall not exceed specified limits in ASME B31.X when tested hydrostatically orpneumatically in accordance with the requirements of ANSI/ ASME B31.12, Hydrogen Piping and Pipelines, either pneumatically or hydrostatically. Thetest pressure shall be not less than 110 percent of the rated service pressure when tested pneumatically, using an inert gas as the medium, nor less than150 percent of the rated service pressure when tested hydrostatically. X.


ASME B31 already specifies how to test valves and the leakage limits. Use existing standards.




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10.3.1.9.1.2

Leakage shall not occur when tested in accordance with the requirements of ANSI/ of ASME B31 .12, Hydrogen Piping andPipelines Code for Pressure Piping , either pneumatically or hydrostatically. The test pressure shall be not less than 110 percent of the ratedservice pressure when tested pneumatically, using an inert gas as the medium, nor less than 150 percent of the rated service pressure when testedhydrostatically.


Standardized title




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10.3.1.10.2

This leak test shall be in addition to the ANSI/ASME B31.3, Process X - Standard of Pressure Piping , testing required by 10.3.1.7.3.


Refer to the appropriate standard.




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10.3.1.10.2

This leak test shall be in addition to the ANSI/ ASME B31 .3, Process Code for Pressure Piping , testing required by 10.3.1.7.3.


Standardized title




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The assembly shall be leak tested using hydrogen or helium in accordance with ASME B31.X using a small molecule non-reactive gas .


Don't specify the media - specify what is needed (small molecule non reactive gas)




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The assembly shall be leak tested using hydrogen or helium .


Personally have encountered hydrogen systems not leaking on helium but leaking on hydrogen. Follow the pneumatic leak test in B31. Low pressure, look for leaks and attended. The raise to high pressure.




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10.3.1.10.3.5 The owner shall maintain a record of the results (e.g. date, operator, pressure, leakage values) which shall be available to the AHJ uponrequest.


If we don’t require documentation, the testing won’t happen. We can't force the AHJ to witness. But we can phrase it so that he knows we would like him to at least spot check.




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10.3.1.10.3. 4 Testing shall be conducted in accordance with the manufacturer’s’ instructions.


The frequency, LOTO procedure and test procedure is best defined by the "expert", the mfg. The procedure belongs in the manuals.




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10.3.1.10.3.1

This leak test shall be conducted following any maintenance that involves breaking a connection or, at a minimum, annually .

10.3.1.10.3.1 A new assembly shall be leak tested at a lower pressure on a non-reactive gas to detect and repair gross leakage, prior totesting at the code pressure levels on hydrogen to detect manageable leak rates.

10.3.1.10.3.2 In case of a local (minor) repair, testing requirements can be reduced to hydrogen at 85% of the safety valve relief setting .


Leak testing should be per the mfg's requirements. Not stipulated by code. the newer clauses are for clarity and practicality. To test a leaking valve packing should not require disabling the safety valves.




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10.3.1.11.2 The owner shall maintain a record of conducting the maintenance in accordance with the manufacturers’ instructions. This record shall beavailable to the AHJ upon request.


If we don’t require documentation, the testing won’t happen.




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10.3.1.11.2.1

Hoses, nozzles, and breakaways shall be examined monthly or according to the manufacturers’ recommendations or at least monthly , whichever periodis shorter, and shall be maintained in accordance with the manufacturers’ instructions.


Grammar




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10.3.1.11.2.4 The owner shall maintain a record of the results (e.g. date, operator, pressure, leakage values, and visual inspection results) which shallbe available to the AHJ upon request.


If we don’t require documentation, the testing won’t happen.




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Public Input No. 63-NFPA 2-2016 [ Sections 10.3.1.11.4, 10.3.1.11.5 ]

Sections 10.3.1.11.4, 10.3.1.11.5

10.3.1.11.4 * x * Fueling Hose Integrity Tests

10.3.x.1

Controllers on hydrogen dispensing systems shall be designed to verify the integrity of the fuel hose, breakaway, nozzle, and receptacle by pressurizingthese components to at least the vehicle back pressure and monitoring pressure decay over a period of at least 5 seconds prior to the start of fueling.

10.3.1.11.5 x.2

Hydrogen dispensing integrity checks once the fueling event has started shall be as follows:

(1) Hydrogen 350 bar fueling events of 350 bar shall have an second integrity check repeated at 85 percent 80 to 90 percent of the dispenser nozzleservice pressure by stopping flow and checking the pressure decay over a period of 5 seconds.

(2) Hydrogen fueling events of 700 bar shall have an integrity check repeated at 45 percent and 85 percent of 700 bar fueling events with a startingpressure of less than 200 bar shall have a second integrity test at 40 to 50 percent and third integrity test at 80 to 90 percent of the dispenser nozzleservice pressure by stopping flow and checking the pressure decay over a period of at least 5 seconds.

(3) 700 bar fueling events with a starting pressure of greater than 200 bar shall have a second integrity test 80 to 90 percent of the dispenser nozzleservice pressure by stopping flow and checking the pressure decay over a period of at least 5 seconds .


The hose leak tests or integrity tests are not part of 10.3.1.11 System Maintenance and should have a separate subsection

the language in (1) and (2) is proposed to be modified for clarity. the proposed change from 45% and 85% to ranges 40 to 50% and 80 to 90 % of the service pressure are intended to give some flexibility to the station designer and may allow the dispenser control system to stop the flow for a bank switch and do an integrity test at the same time

the new text shown as (3) is to cover the condition where cars may come to the dispenser with a partially full tank. if the vehicle presents to the dispenser at > than 30% of the service pressure, the dispenser should not need to do a second integrity test just after the first. the modified langage in (2) and new language in (3) is intended to address this issue.




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Submittal Date: Thu Jun 16 13:48:18 EDT 2016


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10.3.1.11.7

Personnel performing maintenance on hydrogen installations shall be trained and wear personal protective equipment as prescribed in the material safetydata sheets.


osha CHANGED THE TERM




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10.3.1.12

Hydrogen dispensing systems shall be protected to prevent damage from vehicles and to minimize physical damage from vehicles and vandalism vandals .


grammar




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10.3.1.13.A The fueling rate shall maintain the specified range for the ambient temperature and initial pressure of the vehicle tank.

10.3.1.13.B The dispenser gas temperature shall maintain the specified temperature range for the fueling rate.

10.3.1.13.C For light duty vehicles, the dispenser shall not fuel the vehicle if the initial pressure of the container is less than 72.5 psi (0.5 MPa) or greaterthan the service pressure of the container.

10.3.1.13.D For light duty vehicles, the dispenser shall not dispense more than 7 ounces (200g) of hydrogen into the container prior to the start of the mainfueling process.


This proposal adds four important fueling protocol parameters that the dispenser should meet in order to avoid over-pressurizing, overheating, or overfilling a vehicle tank. These parameters are implemented in SAE j2601 the industry fueling protocol standard



Public Input No. 292-NFPA 2-2016 [Section No. 10.3.1.13] The proposed PI should be added to PI 292





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10.3.1.13 Fueling Dispenser System Operation.10.3.1.13.1* Fueling Protocols All public dispensers and all dispensers intended to fuel light duty vehicles shall use a standard automotive fuelingprotocol, such as SAE J2601.

A SAE J2601 fueling protocol is strongly recommended for light duty vehicle dispensers. This standard has been developed by the automotive andhydrogen industry, to ensure that the fueling protocol will not overheat, over-pressurize or overfill the vehicle tank.

10.3.1.13.1.1* A vehicle designed to meet the requirements in a standard automotive fueling protocol may fuel at a dispenser which uses a the samestandard automotive fueling protocol.

A . The intent of this clause is to ensure that a dispenser can fuel any type of vehicle, such as a motorcycle or medium duty vehicle, designed to meet astandard automotive fueling protocol.

10.3.1.13.1.2 * The standard automotive fueling protocol used on the dispenser shall be validated to CSA HGV 4.3 or approved.

A CSA HGV 4.3 is the testing standard designed to validate dispensers use SAE J2601 properly. It cannot be used to validated other standard ornon-standard fueling protocols.

10.3.1.13.1.3* Non-standard automotive fueling protocols All dispensers which use non-standard automotive fueling protocol shall not fuel a vehiclewithout the prior approval of the vehicle owner and vehicle manufacturer.

A Dispensers which use non-standard automotive fueling protocols should never be allowed to fuel vehicles not designed to the protocol. .Doing so couldcause significant damage to the vehicle tank because they may fuel faster which can cause overheating.

10.3.1.13.2 Dispensers for heavy duty and off-road vehicles

All dispensers designed to fuel heavy duty vehicles or off road vehicles shall not fuel light duty vehicles and any other vehicle it is not designed for.

A Forklift and bus dispensers could cause significant damage to light duty vehicle vehicle tanks because they may fuel faster which can cause overheating

10.3.1.13.2.1 An individual dispenser shall not be designed to fuel different classes of vehicle.

10.3.1.13.3* Fueling Authorization Fueling Authorization All dispensers that use a non-standard automotive fueling protocol or designed to fuel heavyduty or off road vehicles shall have hardware or physical barriers to prevent the fueling of vehicles not designed to use the dispenser.

A The intent of this requirement is to prevent unauthorized fueling of light duty vehicles using fueling protocols which can damage the vehicle tank. Somerecommended hardware measures to prevent access include a nozzle which cannot connect to light duty vehicles, a wire from the vehicle to the dispenserthat authorizes the use of the non-standard protocol, or physical barriers that prevent a light duty vehicles from accessing the dispenser.

10.3.1.13.3.1 Measures to prevent fueling of vehicles that require user interface or can be exchanged among users, such as, but not limited to PIN codes,keys, or identification cards, shall not be used to authorize non-standard protocols or fueling for other vehicle classes.


Hydrogen vehicles are challenging to fuel because they heat as they fill. In addition, the dispenser must fuel a vehicle to near full at a high pressure at a specific rate with limited information. Because of these issues, it is critical that dispensers use a fueling protocol that has been developed, validated and approved by both the automotive and hydrogen industry. Not using these protocols could result in overheating, over-pressurizing, or overfilling the vehicle tank. This proposal provides the text to require a "standard automotive fueling protocol". The commentor would prefer to reference J2601 directly, but knows the challenges in doing so given NFPA2 rules.

Dispensers which use non-standard protocols, or are designed to fuel buses and other off road vehicles can cause significant problems for light duty vehicles. Therefore, they must have mechanical means to ensure it is practically impossible to fuel a light duty vehicle. Experience from the field has shown that drivers can easily trade PINs or cards.

Finally, it is critical that the dispenser fueling protocol is validated to CSA HGV 4.3 because this is the only test standard designed test a fueling protocol.

This PI 297should be considered if PI410 is rejected which has a mandatory reference to SAE J2601



Public Input No. 410-NFPA 2-2016 [New Section after 10.3.1.13]





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10.3.1.13 Fueling Dispenser System Operation.

10.3.1.13.1* Fueling Protocols All public dispensers and all dispensers intended to fuel light duty vehicles shall use SAE J2601 fueling protocol.

A SAE J2601 fueling protocol is strongly recommended for light duty vehicle dispensers. This standard has been developed by the automotive andhydrogen industry, to ensure that the fueling protocol will not overheat, over-pressurize or overfill the vehicle tank.

10.3.1.13.1.1* A vehicle designed to meet the requirements SAE J2601 may fuel at a dispenser which uses SAE J2601 fueling protocol.

A . The intent of this clause is to ensure that a dispenser can fuel any type of vehicle, such as a motorcycle or medium duty vehicle, designed to meet aSAE J2601 fueling protocol.

10.3.1.13.1.2 * The fueling protocol used on the dispenser shall be validated to CSA HGV 4.3 or approved.

A CSA HGV 4.3 is the testing standard designed to validate dispensers use SAE J2601 properly. It cannot be used to validated other standard ornon-standard fueling protocols.

10.3.1.13.1.3* Non-standard automotive fueling protocols All dispensers which use non-standard automotive fueling protocols other than SAE J2601shall not fuel a vehicle without the prior approval of the vehicle owner and vehicle manufacturer.

A Dispensers which use non-standard automotive fueling protocols should never be allowed to fuel vehicles not designed to the protocol. .Doing socould cause significant damage to the vehicle tank because they may fuel faster which can cause overheating.

10.3.1.13.2 Dispensers for heavy duty and off-road vehicles

All dispensers designed to fuel heavy duty vehicles or off road vehicles shall not fuel light duty vehicles and any other vehicle it is not designed for.

A forklift and bus dispensers could cause significant damage to light duty vehicle vehicle tanks because they may fuel faster which can causeoverheating

10.3.1.13.2.1 An individual dispenser shall not be designed to fuel different classes of vehicle.

10.3.1.13.3* Fueling Authorization All dispensers that use a non-standard automotive fueling protocol or designed to fuel heavy duty or off roadvehicles shall have hardware or physical barriers to prevent the fueling of vehicles not designed to use the dispenser.

A The intent of this requirement is to prevent unauthorized fueling of light duty vehicles using fueling protocols which can damage the vehicle tank. Somerecommended hardware measures to prevent access include a nozzle which cannot connect to light duty vehicles, a wire from the vehicle to the dispenserthat authorizes the use of the non-standard protocol, or physical barriers that prevent a light duty vehicles from accessing the dispenser.

10.3.1.13.3.1 Measures to prevent fueling of vehicles that require user interface or can be exchanged among users, such as, but not limited to PIN codes,keys, or identification cards, shall not be used to authorize non-standard protocols or fueling for other vehicle classes.


Hydrogen vehicles are challenging to fuel because they heat as they fill. In addition, the dispenser must fuel a vehicle to near full at a high pressure at a specific rate with limited information. Because of these issues, it is critical that dispensers use a fueling protocol that has been developed, validated and approved by both the automotive and hydrogen industry. Not using these protocols could result in overheating, over-pressurizing, or overfilling the vehicle tank. This proposal provides the text to require SAE J2601 fueling protocol. Dispensers which use non-standard protocols, or are designed to fuel buses and other off road vehicles can cause significant problems for light duty vehicles. Therefore, they must have mechanical means to ensure it is practically impossible to fuel a light duty vehicle. Experience from the field has shown that drivers can easily trade PINs or cards. Finally, it is critical that the dispenser fueling protocol is validated to CSA HGV 4.3 because this is the only test standard designed test a fueling protocol.

This PI 410 should be considered prior to PI 297 which is an alternative PI that does not have a mandatory reference to SAE J2601



Public Input No. 297-NFPA 2-2016 [New Section after 10.3.1.13] PI 297 is alternative PI if this PI is rejected





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10.3.1.13 Vehicle Fueling Dispenser System Operation.

10.3.1.13.1

Vehicle Fueling Operating Parameters

10.3.1.13.1.1

GH 2 dispensing systems shall be equipped to stop fuel flow automatically when a fuel supply container reaches the temperature-corrected fill pressure.

10.3.1.13.1.2

The dispenser shall not exceed the service pressure, temperature, or maximum fuel density of the container over the range of dispenser operatingconditions.

10.3.1.13.1.3

The means of protection shall stop the dispensing of hydrogen if the dispenser pressure or dispenser fuel temperature deviate from the operatingparameters.

10.3.1.13 .1 .4

A hydrogen container shall not be charged in excess of the service pressure that is stamped on the container and displayed on a label near the fillingconnection when compensated for differences in temperature from 59°F (15°C).

10.3.1.13.1.1 5

A hydrogen container shall not be subjected to pressure in excess of 125 percent of its marked service pressure.

10.3.1.13. 1.6

The dispenser gas temperature shall be measured as close to the hose breakaway as possible and shall not be less than −40°F (−40°C).

10.3.1.13.1.7

A dispenser shall only dispense hydrogen when the ambient temperature is between −40°F (−40°C) and 122°F (50°C).

10.3.1.13.1.8 *

The flowrate of a hydrogen dispenser for light duty vehicles shall not exceed 0.1323 lb (60 g) of hydrogen per second.

10.3.1.13.1.9

The limit of 0.1323 lb (60 g) per second does not include transient excursions due to valve actuation.

10.3.1.13. 2 Communications Protocol.

10.3.1.13.2.1

Dispensers using a communications protocol to control the fueling shall abort the fill or revert to a noncommunication fueling strategy in the event of acommunications failure.

10.3.1.13.3

GH 2 dispensing systems shall be equipped to stop fuel flow automatically when a fuel supply container reaches the temperature-corrected fill pressure.

10.3.1.13. 4

Where an overpressure incident that results in operation of the overpressure protection system occurs, the dispenser pressure control system shall beexamined and certified by a qualified technician prior to being returned to service.

10.3.1.13.5

The transfer of GH2 into a fuel supply container shall be performed in accordance with instructions posted at the dispensing station.

10.3.1.13.6

Transfer systems shall be capable of depressurizing to facilitate disconnection.

10.3.1.13.7

Bleed connections shall lead to a safe point of discharge.

10.3.1.13.8

GH2 shall not be used to operate any device or equipment that has not been designed or modified for GH2 service.

10.3.1.13.9

Sources of ignition shall not be permitted within 10 ft (3.0 m) of any filling connection during a transfer operation.

10.3.1.13.10

A warning sign with the words “STOP MOTOR, NO SMOKING,, FLAMMABLE GAS, HYDROGEN HAS NO ODOR” shall be posted at each dispenser.

10.3.1.13.10.1

The lettering on the sign shall be large enough to be visible and legible from each point of transfer.

10.3.1.13.11

Pneumatic gas supply systems for control devices shall be designed to prevent internal and external freezing. Fuel gas controls shall be installed to preventexternal freezing.

10.3.1.13.12

Vehicles shall not be considered a source of ignition with respect to the provisions of this chapter.


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10.3.1.13.12.1

Vehicles containing fuel-fired equipment (e.g., recreational vehicles and catering trucks) shall be considered a source of ignition unless this equipment isshut off completely before entering an area in which ignition sources are not permitted.

10.3.1.13.13

A means shall be provided to bring the system to a safe condition in the event of failure of the hydrogen dispensing system logic controller.

10.3.1.13.13.1

The means of protection shall stop the dispensing of hydrogen if the dispenser pressure or dispenser fuel temperature deviate from the operatingparameters.

10.3.1.13.14

The dispenser gas temperature shall be measured as close to the hose breakaway as possible and shall not be less than −40°F (−40°C).

10.3.1.13.15

A dispenser shall only dispense hydrogen when the ambient temperature is between −40°F (−40°C) and 122°F (50°C).

10.3.1.13.16 *

The flowrate of a hydrogen dispenser for light duty vehicles shall not exceed 0.1323 lb (60 g) of hydrogen per second.

10.3.1.13.16.1

The limit of 0.1323 lb (60 g) per second does not include transient excursions due to valve actuation.

10.3.1.13.17

The dispenser shall not exceed the service pressure, temperature, or maximum fuel density of the container over the range of dispenser operatingconditions.


This proposeal moves 10.3.1.13.1 and 10.3.1.13.14-17 into the same section because all of these requirements relate to the fueling protocol and the dispenser's implementation of the fueling protocol. By maintaining these parameters, the dispenser will ensure that a vehicle is not overheated, overpressurized, or filled above 100% density. The order of the sub-sections have changed to better reflect their importance. There have been no changes to the text



Public Input No. 296-NFPA 2-2016 [New Section after 10.3.1.13]





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10.3.1.13.1.2 A hydrogen container shall not be subjected to pressure in excess of its marked maximum allowable working pressure.


Now addresses ASME vessels




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10.3.1.13.1.1

A hydrogen container shall not be subjected to pressure in excess of 125 percent of its marked service pressure or the name plate value for maximumallowable working pressure (MAWP) . .


did not address ASME vessels




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10.3.1.13.2 Communications Protocol.

10.3.1.13.2.1

Dispensers using

Vehicle to Dispenser Communications System.

10.3.1.13.2.2* Dispensers shall use a communication system approved by the manufacturer of the vehicle it is fueling. The communication systemdefined in SAE J2799 is recommended.

A SAE J2799 communication protocol is strongly recommended for light duty vehicle dispensers. This standard has been developed by the automotiveand hydrogen industry to ensure the proper information is passed from the vehicle to ensure that the fueling protocol will not overheat, over-pressurize oroverfill the vehicle tank.

10.3.1.13.2.3 The operating of the communication system using SAE J2799 shall be validated to CSA HGV 4.3 or approved.

10.3.1.13.2.4 The dispenser shall automatically prevent fueling of vehicles whose manufacturer has not approved the communication protocol.

10.3.1.13.2.5 Dispensers using a communications protocol to control the fueling shall abort the fill or revert to a noncommunication fueling strategy in theevent of a communications failure.


This PI proposes to limit the communications system to one approved by the vehicle manufacturer, and encourages SAE J2799 which is the industry standard for vehicle to dispenser communication. This is important because conflicting communications systems could send signals that are mis-interpreted by the dispenser, and could result in issues in fueling the vehicle. For example, if the pressure signal is different by a factor of 10, the dispenser could over-pressurize the tank. The PI also requires validation to HGV 4.3 which ensures that the industry standard vehicle to dispenser communication system is properly tested.





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10.3.1.13.2.1

Manufacturer's certification of compliance shall be permissible as evidence of compliance with requirements that are not phsically verifiable or able to beconfirmed during a functional test.


Chapter 10 contains functional requirements that are not readily verifiable by AHJs. Adding this text allows manufacturers to certify compliance with requirements that may be embedded in software but not able to be confirmed via a functional test.




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10.3.1.13.3

GH2 dispensing systems shall be equipped to stop fuel flow automatically when a fuel supply container reaches the temperature-corrected fill pressure or

target density .


A dispenser can fill to a target density thereby providing more range for the vehicle. The proposed change allow for this option.





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10.3.1.13.7

Bleed connections shall lead to Hydrogen that is vented when the dispenser nozzle is disconnected from the vehicle shall be directed to a safe point ofdischarge.


this text is in the dispenser section and where there is a bleed down of pressure associated with disconnection of the dispensing nozzle from the vehicle receptacle. The revised text clarifies the intention of the requirement for safety operation of the dispenser.




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10.3.1.13.8

GH2 shall not be used to operate any device or equipment that has not been designed or modified for GH2 service.


If an engineer redesigns a product, it has been “designed”. If a tradesman reworks a product it is modified. We don’t want modified, we want designed.




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10.3.1.13.9

Sources of ignition shall not be permitted within 10 ft 5 ft (3 1 .0 m 5 m ) of any filling connection during a transfer operation. Refer to 10.3.1.13.12


Task group consensus is to: • use a 5 ft separation for consistency with other NFPA documents.• include call out for user




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10.3.1.13.10.1

The lettering on the sign shall be large enough to be visible and , be legible from each point of transfer and conform to NEMA Z535 .


NEMA Z535 is a OSHA regulation.




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10.3.1.13.12.2 Gas turbine powered vehicles (e.g. some CNG vehicles) shall not be considered a source of ignition while operating.


Shutting done a CNG turbine may be problematic. However, the vehicle design should have addressed C1D2 lighter than air fuels.




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10.3.1.13.13.1

The dispenser shall have means of protection shall to stop the dispensing of hydrogen if the dispenser pressure or dispenser fuel temperature any of thefueling protocol parameters deviate from the maximum or minimum operating parameters.


The previous clause was confusing. The proposed change clarifies the meaning and also specifies the max/min operating parameters





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10.3.1.13.15

A dispenser shall only dispense hydrogen when the ambient temperature is between −40°F (−40°C) and 122°F (50°C) unless designed for extremetemperatures and clause 10 .3.1.13.17.


NFPA documents have been adopted outside of the contiguous 48 states. Areas in the Persian gulf that have adopted NFPA exceed these limits




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10.3.1.14.2

The use of adapters to transition from the nozzle to the vehicle shall be prohibited.


Task group consensus




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With the approval of the authority having jurisdiction, the classified areas specified in Table 10.3.1.15.1 shall be permitted to be reduced or eliminated bypositive pressure ventilation from a source of clean air or inert gas in conjunction with effective safeguards against ventilator ventilation system failure bypurging methods recognized in NFPA 496.


a ventilator is a piece of sheet metal that rotates due to the natural draft of a heat source beneath it. The correct term is "ventilation system".




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10.3.1.15.2.1

Modifications shall be approved by a qualified engineer with expertise in fire safety and gaseous fuels.


This statement makes no sense. A dispenser must be designed by a professional and ideally labeled and listed. This means the only allowable changes are design changes approved by the NRTL or the AHJ. Modifications are prohibited.




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An emergency manual shutdown device shall be provided at the dispensing area and also at a location remote from the dispensing area. Placement shallbe determined by local regulation or lacking local regulation by safety analysis.


This document requirement is incomplete. We state a need without any guidance. The placement of E-Stops for petroleum varies from state to state based on experience. It should be expected that the local AHJ will have input here. The addition is to remind the owner/operator that the AHJ will most likely determine the placement. Knowing this the owner/operator will likely request input on placement prior to installation to avoid costly rework.




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10.3.1.18 * Fire Protection . A portable fire extinguisher having a rating of not less than 4-A: 80-B:C shall be provided at the dispensing area in approvedlocations not more than 50 ft (15.2 m) away from the dispensing area. Fire extinguishers shall be inspected and maintained according to NFPA 10.

10.3. 1 .18.1

Dispensing equipment shall be provided with hydrogen gas de tection, leak detection, and flame detection at the fueling area.

10.3.1.18.1.1

The detection systems shall be maintained and calibrated in accordance with Chapter 6

10.3.1.18.1.2

The station owner or operator shall maintain a record of detector maintenance and calibration in good condition and accessible to the inspector.

10.3.1.18.1.3

Activation of the detection systems shall automatically stop dispensing and activate the automatic emergency shutoff valve. Reactivation of the dispenserrequires a manual restart following the provisions of this chapter.

10.3.1.18.1.4

Dispenser enclosure shall be designed to prevent the accumulation of flammable gas within the enclosure.


The 80-B rating is in keeping with the minimum rating required for dispensing gasoline in NFPA 30A. The addition of the A rating was the result of reading the annex material which says the extinguisher is to control surrounding fires, thus the 4-A rating. This is also in keeping with the rating of a 10 pound ABC extinguisher which has a rating of 4-A:80-B:C.


Submitter Full Name: Jennifer Boyle

Organization: FEMA

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10.3.1.18.1.2

T The station owner or operator owner/operator shall maintain a record of detector maintenance and calibration in good condition and accessible tothe inspector. . These records shall be readily available to the AHJ upon request and be maintained for a minimum of three (3) years.


The use of owner or operator versus owner/operator is left to the NFPA 2 editor staff, it is a style question.




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10.3.1.18.1.3

Activation of the detection systems shall automatically stop dispensing and

activate thedetermine the cause of the activation and the system shall respond properly to the detected event. As a minimum, the system should stop dispensing fuelfrom the dispenser in the event area by activating that dispenser’s activate automatic emergency shutoff valve.

Reactivation of the dispenser equipment disabled by the detection of the event shall require requires a manual restart following the provisions of thischapter.


Working group advances to committee requesting assistance with wordsmithing.

An alarm activates the safety system. The safety system decides upon the correct response and initiates the action.




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10.3.1.19 Canopies Used to Support Gaseous Hydrogen Systems.

Canopies that are used to shelter dispensing operations where flammable compressed gases are located on the roof of the canopy shall be in accordancewith the following:

(1) The canopy shall meet or exceed Type I construction requirements of the adopted building code. Type I construction is defined in NFPA 5000Section 7.2.1.1.

(2) Operations located under canopies shall be limited to refueling only.

(3) The canopy shall be constructed in a manner that prevents the accumulation of hydrogen gas.


Where is type I construction defined? Type I construction is defined in NFPA 5000 Section 7.2.1.1.

The working group tabled for the next edition whether or not type I is excessive. Would type II or type III be more appropriate? A dispenser or car fire event will not last for multiple hours. A dispenser fire is likely to be less than a couple of minutes as would a hydrogen vehicle PRD release. A pool fire from a petroleum fueled vehicle would most likely be resolved under 1 hour.




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10.3.2.3.1.3*

The vehicle fueling pad shall be of concrete or a material having a resistivity not exceeding 1 megaohm 1 megaohm when measured at a potential of500 V d.c. as determined by an approved method unless the vehicle is grounded by other means, such as a grounding cable .


This is not actionable. How is this to be measured?

In NFPA 79 section 18.3 the insulation resistance test is done at 500 V dc and acceptance is a resistance of >1 megaohm. UL 508 section 49 has similar verbiage.




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(B)

VFAs shall be listed or approved .


Currently there is an insufficient number of components listed. For the near term this becomes an AHJ approval task until the market demand is sufficient to amortize the cost of a product safety listing with a NRTL.




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Public Input No. 122-NFPA 2-2016 [ Section No. 10.3.3.2.1.1(C) ]

(C)

The installation of VFAs shall be in accordance with the manufacturer’s instructions and the listing .


The manufacturer’s instructions are part of the listing and require change control and NRTL approval. It is treated the same as if it were a part in the device.




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Public Input No. 351-NFPA 2-2016 [ Section No. 10.3.3.2.2(E) ]

(E) Rooms Within Buildings.

Rooms within or attached to other buildings shall be constructed of noncombustible or limited-combustible materials.

Exception: Window glazing shall be permitted to be plastic.

(1) Interior walls or partitions shall be continuous from floor to ceiling, shall be anchored, and shall have a fire resistance rating of at least 2 hours.Rooms containing dispensing equipment and dipensing operations only shall not be required to have a fire resistance rating.

(2) At least one wall shall be an exterior wall.

(3) Explosion venting shall be provided in accordance with 10.3.3.2.2(B) and 10.3.3.2.2(C).

(4) Access to the room shall be from outside the primary structure.

(5) If access to the room from outside the primary structure is not possible, access from within the primary structure shall be permitted where such accessis made through a vapor-sealing, self-closing fire door having the appropriate rating for the location where installed.


Reason: When looking at the existing language and the history of its development, it makes sense to require the 2 hour fire resistance rating when storage, compression, or gas processing is included within the space to protect that space from a fire threat from within the rest of the building. But that level of protection is not needed when only dispensing equipment and operations are present with the storage, compression, or gas processing located elsewhere.



Public Input No. 352-NFPA 2-2016 [Section No. 10.3.3.2.2(P)]





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Public Input No. 123-NFPA 2-2016 [ Section No. 10.3.3.2.2(F) ]

(F) Ventilation.

(1) Indoor locations shall be ventilated utilizing air supply inlets and exhaust outlets arranged to provide uniform air movement to the extent practical.

(2) Inlets shall be uniformly arranged on exterior walls near floor level .

(3) Outlets shall be located in exterior walls at the high point of the room or in the roof.


This is room temperature H2 (1/14th the density of air. We need to sweep the ceiling not the floor. Floor level vents get block with snow, ice, leaves, sticks, etc. Additionally, if petroleum is used in the area, a minimum height of 18” would be appropriate.




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Public Input No. 373-NFPA 2-2016 [ Sections 10.3.3.2.2(F), 10.3.3.2.2(G), 10.3.3.2.2(H) ]

Sections 10.3.3.2.2(F), 10.3.3.2.2(G), 10.3.3.2.2(H)

(F) Ventilation.

Indoor locations shall be ventilated

utilizing air supply inlets and exhaust outlets arranged to provide uniform air movement to the extent practical.

Inlets shall be uniformly arranged on exterior walls near floor level.

Outlets shall be located in exterior walls at the high point of the room or in the roof.

(G) Room Ventilation.

(1) Ventilation shall be by a continuous mechanical ventilation system or by a mechanical ventilation system activated by a continuously monitoringhydrogen detection system where a gas concentration of not more than one-quarter of the lower flammable limit is present.

(2) In either case in 10.3.3.2.2(F) (D)(1), the system shall immediately shut down the fueling system in the event of detection of an alarm condition orfailure of the ventilation system, the detection system, or of the controls.

(H)

The ventilation rate shall be at least 1 ft 3 /min/ft 2 (0.3 m 3 /min/m 2 ) of room area, but no less than 1 ft 3 /min/12 ft 3 (0.03 m 3 /min/0.34 m 3 ) of roomvolume.

in accordance with the requirements of Section 6.17.












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Public Input No. 124-NFPA 2-2016 [ Section No. 10.3.3.2.2(H) ]

(H)

The ventilation rate shall be at least 1 ft least 60 ft 3 / min hr /ft 2 ( 0.3 m 18 m 3 / min hr /m 2 ) of of room area, but no less than 1 ft than 5

ft 3 / min hr / 12 ft ft 3 ( 0.03 m 5 m 3 / min hr / 0.34 m m 3 ) of of room volume.


This is an ANSI standard. ANSI standards conform to ANSI SI-10 for metric units. SI-10 uses seconds and hours for time, not minutes.

Upon further review, in hours it becomes nice round numbers. Almost like the original numbers were SWAGs.




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Public Input No. 128-NFPA 2-2016 [ Section No. 10.3.3.2.2(J) ]

(J)

Where installed, a gas detection system shall be equipped to sound a latched an alarm which requires a manual reset and visually indicate when amaximum of one-quarter of the lower flammable limit is reached.

(1) The gas detection system shall be certified by a qualified engineer with expertise in fire safety and gaseous detection.


Latched alarm is not defined.




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Public Input No. 129-NFPA 2-2016 [ Section No. 10.3.3.2.2(L) ]

(L)

Reactivation of the fueling system shall be by manual restart reset and shall be conducted by trained personnel.


The operator reset the controls. The controls evaluate it the fault persists, if the fault clears the controls initiates a restart.




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Public Input No. 130-NFPA 2-2016 [ Section No. 10.3.3.2.2(O) ]

(O) Warning Signs.

(1) Access doors shall have warning signs with the words “WARNING — NO SMOKING — FLAMMABLE GAS.” “HYDROGEN HAS NO ODOR.”

(2) The wording shall be in plainly legible, bright red letters not less than 1 in. (25 mm) high on a white background.

(3) All markings, placards and symbols shall be in compliance with ANSI/NEMA Z535.


OSHA regulation




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Public Input No. 131-NFPA 2-2016 [ Section No. 10.3.3.2.2(P) ]

(P) Construction of Indoor Areas. Walls, ceilings, and floors within 15 feet (4.

6 m

6 m ) of the dispenser shall be constructed as fire barriers having a fire resistance rating not less than

2 hours.

2 hours.

(A) Walls within 15 feet (4.6 m) of the dispenser shall be constructed as fire barriers having a fire resistance rating not less than 2 hours.

(B) Openings. Opening protectives shall be provided for wall openings in accordance with the requirements of the adopted building code.

(C) Penetrations. Through-penetrations and membrane penetrations of fire resistance rated construction shall be protected in accordance with therequirements of the adopted building code.

(D) Roof-Ceiling Assemblies.

The fireRoof or ceilings less than 20 ft (6.1 m) above the floor immediately below shall be constructed as fire barriers having a fire resistance rating not lessthan 2 hours. fire -resistive protection of a roof-ceiling assembly required by 10.3.3.2.2

(P).16 shall not be required where every part of the roof-ceiling assembly is

20 ft20 ft (6.

1 m1 m ) or more above any floor immediately below.

(E) Attics. Open attics above the dispensing area are prohibited.

(F) Floors. Floors in dispensing areas constructed of noncombustible or limited-combustible materials shall not be required to comply with10.3.3.2.2

(P). 16.


There is a discrepancy for roof/ceilings. The charging statement stated 15’ and paragraph D stated 20’. Many buildings have open attics. Attics can provide a pathway for hydrogen to migrate within a building and should be prohibited.




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Public Input No. 352-NFPA 2-2016 [ Section No. 10.3.3.2.2(P) ]

(P) Construction of Indoor Areas.

Walls, ceilings, and floors within 15 feet (4.6 m) of the dispenser shall be constructed as fire barriers having a fire resistance rating not less than 2 hours.Rooms containing dispensing equipment and dispensing operations only shall not be required to have a fire resistance rating.

(1) Openings. Opening protectives shall be provided for wall openings in accordance with the requirements of the adopted building code.

(2) Penetrations. Through-penetrations and membrane penetrations of fire resistance rated construction shall be protected in accordance with therequirements of the adopted building code.

(3) Roof-Ceiling Assemblies. The fire-resistive protection of a roof-ceiling assembly required by 10.3.3.2.2(P) shall not be required where every part ofthe roof-ceiling assembly is 20 ft (6.1 m) or more above any floor immediately below.

(4) Floors. Floors in dispensing areas constructed of noncombustible or limited-combustible materials shall not be required to comply with 10.3.3.2.2(P) .


Reason: When looking at the existing language and the history of its development, it makes sense to require the 2 hour fire resistance rating when storage, compression, or gas processing is included within the space to protect that space from a fire threat from within the rest of the building. But that level of protection is not needed when only dispensing equipment and operations are present with the storage, compression, or gas processing located elsewhere.



Public Input No. 351-NFPA 2-2016 [Section No. 10.3.3.2.2(E)] Similar requirement





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10.3.3.2.3.1

Fast-fill fueling indoors shall be permitted where storage, gas processing, and compression equipment is located outdoors complying with 10 7 .3.2.3. 1.1through 10.3.2.3.1.6 .


Sections 10.3.2.3.1.1 to 10.3.2.3.1.6 apply to outdoor public fueling and are not appropriate here. The intent is to assure that the hydrogen equipment except for the indoor dispenser are located outdoors and are compliant with the code. Pointing to section 7.3.2.3 is more general and appropriate




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(A)

Ventilation shall be in accordance with 10.3.3.2.2(F) . the provisions of Section 6.17.

(B)

The ventilation system of 10.3.3.2.2(F) of Section 6.17 shall not be required in industrial and storage occupancies when the room or area in whichdispensing occurs is in accordance with the following:

(1) The minimum volume of the room in which a dispenser is installed shall be not less than 180,000 ft3 (5000 m 3), and the maximum quantity of fuel tobe dispensed per fueling event shall be limited to 9.2 lb (4.2 kg).

(2) The dispenser shall be equipped with an automatic shutoff control to shut down the source of fuel when the maximum fuel quantity per dispensingevent is reached or when the vehicle has been fueled to capacity, whichever is less.

(a) The shutoff control shall be tested at installation and annually thereafter.

(b) Failure of the controller shall shut down the dispensing system.

(3) When multiple dispensers are installed in a room, the minimum room volume shall be incrementally increased for each additional dispenser.

(4) The height of the ceiling of the room where dispensing occurs shall be not less than 25 ft (8 m).

(5) The maximum refueling rate shall be limited to not more than 2.2 lb/min (1 kg/min), and the flow limiting device shall be installed outdoors.

(6) All potential leak points between the dispenser cabinet and the refueling nozzle shall be monitored by the dispenser in accordance with 10.3.1.11.4and 10.3.1.11.5. Activation of the monitoring system shall shut down the dispensing system.

(7) The fueling hose shall be limited to a maximum length of 25 ft (7.6 m) and shall be protected from mechanical damage, from abrasion, and from beingdriven over by a vehicle.

(a) Transfer systems shall be capable of depressurizing the nozzle through the dispenser vent line to facilitate disconnection.

(8) The dispensing area shall be inspected annually and certified in accordance with 10.1.1.1.












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(A)

Ventilation shall be in accordance with 10.3.3.2.2(F) . the mechanical code.


No special ventilation requirements are needed. A typical application is in an existing warehouse. Because the room volume requirements of this section require a large room 180,000 cubic feet or larger, additional ventilation requirements beyond those normally applicable to storage occupancies inthe mechanical code are not warranted. This text will avoid misapplication of hazardous exhaust systems which are not warranted.




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Public Input No. 125-NFPA 2-2016 [ Section No. 10.3.3.2.3.3 [Excluding any Sub-Sections] ]

The electrical area classification for the dispenser shall be Class 1 Division 2 Group B within 15 ft (4.6 m) of the point of transfer during filling.


Group B adds clarification to the electrical classification. Adds detail of the impact of other fuels on a hydrogen system.




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The electrical area classification for the dispenser shall be Class 1 Class I, Group B, Division 2 or Class I, Group IIC, Zone 2 within 15 ft (4.6 m) of thepoint of transfer during filling.


Two issues here, NFPA 70 "Class" designations are in Roman numerals. The added NFPA 70 Article 505 designation (Class I, Group IIC, Zone 2) is being added to be inclusive of the alternate IEC information provided by Article 505. This change makes NFPA 2 more universal and applicable in countries that subscribe to the IEC classification methods.




Public Input No. 9-NFPA 2-2016 [Section No. 14.3.1.2.2 [Excluding any Sub-Sections]]


Public Input No. 11-NFPA 2-2016 [Section No. A.16.2.2.1]


Submitter Full Name: Larry Danner

Organization: GE Power Water

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Submittal Date: Mon Feb 08 15:06:19 EST 2016


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Public Input No. 126-NFPA 2-2016 [ New Section after 10.3.3.2.3.3(B) ]


(C) If a hydrogen dispenser is sited within the classified area of another fuel, the hydrogen dispenser shall be constructed to also meet the areaclassification for the non-hydrogen dispenser.

(D) If a non-hydrogen dispenser is sited within the classified area of the hydrogen system, the non-hydrogen dispenser shall be constructed to also meetthe area classification for the hydrogen dispenser


Adds detail of the impact of other fuels on a hydrogen system and vice versa.




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Public Input No. 369-NFPA 2-2016 [ Sections 10.3.3.2.3.4, 10.3.3.2.3.5 ]

Sections 10.3.3.2.3.4, 10.3.3.2.3.5

10.3.3.2.3.4 Fire Detection Alarm System.

The dispensing room or area shall be equipped with a automatic fire detection system designed per NFPA 72 to cover the dispensing area .

(A)

Actuation of an alarm, supervisory, or trouble signal on the fire detection alarm system shall shut down the gas flow from the dispenser and stop the flowof gas into the piping system located in the room where dispensing occurs.

(B)

Actuation of an alarm signal on the fire detection alarm system shall sound a local fire alarm signal to alert building occupants of a fire in the dispensingarea and shall provide a visual indication initiate audible and visual notification in the dispensing area of an alarm condition .

(C)

The fire detection system shall be maintained in an operational condition when the dispenser is either operating or being maintained.

(1) An interlock shall be provided so that the dispenser will not operate if the fire alarm is not operational.

10.3.3.2.3.5 Fire Alarm System.

The dispensing area shall be equipped with a protected premises (local) fire alarm system in accordance with NFPA 72 .

(A)

Manual Fire Alarm Boxes. A manual fire alarm box shall be located not Manual fire alarm boxes shall be located:

(1) Not less than 20 ft (6.1 m) and not more than 100 ft (30.5 m) from the dispensing station.

An additional manual fire alarm box shall be located at(2) At the nearest building exit from the dispensing area.

Activation of the fire alarm box shall sound a local fire alarm signal to alert building occupants of a fire in the dispensing area and shall shut down thedispenser, stop the flow of gas into the room, and start or continue to run the ventilation system(D)

The requirements of this section do not require a full fire alarm system for the remainder of the building where none is required by the fire code .


The requirements for a fire alarm system are only intended to apply to the area of dispensing. Required initiating devices are fire detectors that cover the fueling area and manual pulls as specified. In a building with no current fire alarm system or without full notification, these requirements are not intended to require such systems. The section does require both audible and visual notification in the area of fueling - but not necessarily the entire building. The revisions are intended to make the requirement more clear.




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(B) Manual Shutoff Valve.

A fast-closing, “quarter turn” manual shutoff valve shall be provided at a fast-fill station upstream of the breakaway device specified in 10.3.1.17.6, where itis readily accessible to the person dispensing hydrogen, unless one of the following occurs:

(1) The self-closing valve referred to in 10.3.3.2.3.7(A) is located immediately upstream of the dispenser.

(2) The dispenser is equipped with a self-closing valve that closes each time the control arm is turned to the OFF position or when the ESD is activated.


Faster closing is redundant with quarter turn and does not provide greater direction. You don't buy a fast closing hand valve. You buy a 1/4 turn valve.




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Public Input No. 132-NFPA 2-2016 [ Section No. 10.3.3.2.3.7(D) ]

(D) Reactivation.

Reactivation of the dispenser and gas flow into the room after system shutdown required by 10.3.3.2.3.7(A) or 10.3.3.2.3.7(C) shall be by manual restartrest and shall be conducted by trained personnel.


We reset controls. Controls check to see if the fault persists and if it does not, restarts system




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(D) Piping and Hose.

The use of hose in an installation shall be restricted to the following:

(1) A fueling hose that is limited to a maximum length of 25 ft (7.6 m) and is protected from mechanical damage from abrasion and from being driven overby a vehicle.

A maximum of 3 ft (1 m) in length where used to prevent abrasion damage resulting from vibration on the inlet, outlet, or both

(2) When hose is used as a thermal expansion joint, an alignment joint, or as part of a vibration damping system, the length shall not exceed 3 ft (0.9 m)in length .

(3) Transfer systems shall be capable of depressurizing the nozzle to facilitate disconnection.

(4) Bleed connections shall lead to a safe point of discharge.


Clarification of intent




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(D) Piping and Hose.

The use of hose in an installation shall be restricted to the following:

(1) A fueling hose that is limited to a maximum length of 25 ft (7.6 m) and is protected from mechanical damage from abrasion and from being driven overby a vehicle.

(2) A maximum of 3 ft (1 m) in length where used to prevent abrasion damage resulting from vibration on the inlet, outlet, or both.

(3) Transfer systems shall be capable of depressurizing the nozzle to facilitate disconnection.

Bleed connections shall lead

(4) If the piping system or nozzle assembly includes means to to vent hydrogen, the vented hydrogen shall be directed to a safe point of discharge.


Clarifies that “bleed” means to vent hydrogen or depressurize the system




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Public Input No. 135-NFPA 2-2016 [ Section No. 10.3.3.3.5.2(G) ]

(G)

Persons performing dispensing operations shall be qualified trained and authorized by the bulk supplier or the transport owner/operator to deliver anddispense GH 2 fuels.


The trainee could be an employee of either the bulk supplier or the transport owner/operator. Trained and authorized offers greater clarity than qualified.




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11.2.1 Hazard Analysis.

All hydrogen refueling station sites shall have a complete HAZOP or process safety analysis prior to dispensing fuel.

11.2.1.1

The hazard safety analysis shall be updated when changes to the process affect operating limits or design specifications that were included as the basisfor the original hazard analysis.


HAZOP, hazard or process safety infer specific methodology. Safety analysis is more generic.




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11.2.2 Security.

LH2 dispensers shall be designed to secure all equipment from tampering be tamper resistant .


Impossible to be tamper (or idiot) proof, best we can do is tamper (or idiot) resistant. A vandal (or idiot) will always find a way to beat the tamper proofing.




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11.2.7 Fire Extinguishers.

Each motor fuel dispensing facility or repair garage shall be provided with fire extinguishers installed, inspected, and maintained as required by NFPA 10.Extinguishers for outside motor fuel dispensing areas shall be provided according to the extra (high) hazard requirements for Class B hazards, except thatthe maximum travel distance to a 80 B:C extinguisher shall be permitted to be 100 ft (30 . 48 m). [30A:9.2.5.2]


According to NFPA 10, an Extra Hazard would necessitate a 40-B extinguisher at 30 ft or an 80-B extinguisher at 50 ft. The text in NFPA 2 allowing the maximum travel distance for an 80-B extinguisher should be deleted as it conflicts with NFPA 10.

NFPA 10 provides the following information in the annex to support the 50 ft travel distance:E.4.4 The reason the basic maximum travel distance to Class B fire extinguishers is 50 ft (15.25 m), as opposed to 75 ft (22.9 m) for Class A fire extinguishers, is that flammable liquid fires reach their maximum intensity almost immediately. It is imperative that the fire extinguisher be brought to the fire in a much shorter period of time than that allowed for a slower developing Class A fire.



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11.2.8 Piping, Tubing, and Fittings.

11.2.8.1

Pipe, tubing, and fittings shall be designed for hydrogen service and for maximum pressures and minimum and maximum temperatures.

11.2.8.1.1

Pipe, tubing, fittings, gaskets, and packing material shall be compatible with the fuel under service conditions.

11.2.8.1.2

Pipe, valves, and fittings fabricated from cast, Ductile, Malleable, and High Silicon iron or carbon steel shall not be used.

11.2.8.2

Pipe, tubing, fittings, and other components shall be designed with a minimum safety factor of 3.

11.2.8.3

Hydrogen gas piping shall be fabricated and tested in accordance with ANSI/ ASME B31 .3, Process Code for Pressure Piping .

11.2.8.4

Piping components such as strainers, snubbers, and expansion joints shall be permanently marked by the manufacturer to indicate the service ratings.

11.2.8.5 Installation of Piping and Hoses on Dispensing Systems.

11.2.8.5.1

Piping and hose shall be protected from the effects of expansion, contraction, jarring, vibration, and settling.

11.2.8.5.2

Manifolds connecting fuel containers shall be fabricated to minimize vibration and shall be installed in a protected location or shielded to prevent damagefrom unsecured objects.

11.2.8.5.3

Joints or connections shall be located in an accessible location.

11.2.8.5.4

The number of joints shall be minimized and placed in a location considering hazards to personnel safety.

11.2.8.5.5

Hydrogen shall be vented in accordance with Section 6.16.


ASME B31 Code for Pressure Piping, section 12 clause GR-2.1.4 Fluid Service Requirements for Materials

(b) Specific Material Considerations — Metals. The following are some specific considerations that should be evaluated when selecting certain metals in piping:

(1) Irons — Cast, Ductile, Malleable, and High Silicon (14.5%). Due to their lack of ductility and their sensitivity to thermal and mechanical shock, these materials are prohibited.




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11.2.10 Pressure Relief Devices — Vaporizers.

The discharge from pressure relief devices serving the vaporizer system shall be connected to a vent pipe system.


What vaporizers? This is Chapter 11 LH2 Fueling Facilities. This item belongs in liquid storage (back court not front court).




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11.2.11.2* Pressure Gauges Instrumentation .

Pressure monitoring systems or indicating devices shall be capable of reading at least 1.2 times the system maximum allowable working pressure (MAWP).


21st century will most likely use transducers and switches, not gauges.. More accurate, more reliable.




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11.2.12.1

Electrical equipment and wiring shall be as specified by and shall be installed in accordance with NFPA 70 and shall meet the requirements of Class I,Group B, Division or Zone as specified in Table 11.2.12.1.

Table 11.2.12.1 LH2 Fueling Facility Electrical Area Classification

Part Location

Class I, Group B Division

or Zonea Extent of Classified Areab

APits, trenches, or sumps located in or adjacent to Division 1 or2 areas

1 Entire pit, trench, or sump

B Discharge from relief valves, drains 1 Within 5 ft (1.5 m) from point of discharge

2Beyond 5 ft (1.5 m) but within 25 ft (7.6 m) in alldirections from point of discharge

C Vehicle/cargo transfer area

Outdoors in open air at or above grade 1 Within 3 ft (1 m) of connection

Points where connections to the hydrogen system are

regularly made and disconnectedc 2 Between 3 ft (1 m) and 25 ft (7.6 m) of connection

aSee Article 500, “Hazardous (Classified) Locations,” in NFPA 70 for definitions of classes, groups, and divisions.

bThe classified area not to extend beyond an unpierced wall, roof, or solid vaportight partition.

cIndoor fueling with LH2 is not permitted. See 11.3.2.

dVentilation is considered adequate when provided in accordance with the provisions of this code.

11.2.12.1.1

Electrical equipment

on internal combustion engines

and wiring shall be as specified by and shall be installed in accordance with

NFPA 37.

NFPA 70 and shall meet the requirements of any other flammable fluids in use at this facility


Delete the original text. It belongs in Chapter 12 and a rested changge has been submitted.

Inert proposed test.. Fueling stations will most likely have multiple fuels. The fuel will interact, the requirements must also interact.




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Electrical equipment and wiring shall be as specified by and shall be installed in accordance with NFPA 70 and shall meet the requirements of Class I,Group B, Division or Class I, Group IIC, Zone as specified in Table 11.2.12.1.

Table 11.2.12.1 LH2 Fueling Facility Electrical Area Classification

Part Location

Class I, Group B

or Group IIC, Division

or Zonea Extent of Classified Areab

APits, trenches, or sumps located in or adjacent to Division 1 or 2areas

1 Entire pit, trench, or sump

B Discharge from relief valves, drains 1 Within 5 ft (1.5 m) from point of discharge

2Beyond 5 ft (1.5 m) but within 25 ft (7.6 m) in all directionsfrom point of discharge

C Vehicle/cargo transfer area

Outdoors in open air at or above grade 1 Within 3 ft (1 m) of connection

Points where connections to the hydrogen system are regularly

made and disconnectedc 2 Between 3 ft (1 m) and 25 ft (7.6 m) of connection

aSee Article 500, “Hazardous (Classified) Locations,” in NFPA 70 for definitions of classes, groups, and divisions or Article 505, "Zone 0, 1, and 2Locations" in NFPA 70 for definition of Class I Zones and associated Gas Groups .

bThe classified area not to extend beyond an unpierced wall, roof, or solid vaportight partition.

cIndoor fueling with LH2 is not permitted. See 11.3.2.

dVentilation is considered adequate when provided in accordance with the provisions of this code.


The added NFPA 70 Article 505 information (Class I, Group IIC, Zone 2) is being added to be inclusive of the alternate IEC information provided by Article 505. This makes NFPA 2 more universal and applicable in countries that subscribe to the IEC classification methods.



Public Input No. 7-NFPA 2-2016 [Section No. 10.3.3.2.3.3 [Excluding any Sub-Sections]] Similar change




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11.2.12.2

Static protection shall be required when LH2 cargo transport vehicles are unloaded, except where cargo transport vehicles or marine equipment are loaded

or unloaded by conductive hose, flexible metallic tubing, or pipe connections through or from tight (top or bottom) outlets where both halves of metalliccouplings are in contact (bonded) .


Clarity




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11.2.14.1.2

Records of required maintenance shall be provided to the authority having jurisdiction upon request. Details of this program shall be available to the AHJupon request.


Need a stick or it will not happen.




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11.2.14.5.1

All maintenance and servicing shall be done in accordance with 29 CFR 1910 for energy control.(Lock out/Tag out).


Clarity




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11.2.14.8 Hose Assemblies.

11.2.14.8.1

Hoses, nozzles, and breakaways shall be examined according to the manufacturers’ recommendations or at least monthly and shall be maintained inaccordance with the manufacturers’ instructions.

11.2.14.8.2

Hose shall be tested for leaks per manufacturer’s requirements, and any unsafe leakage or surface cracks shall be reason for rejection and replacement.

11.2.14.8.3

Testing shall be carried out using an inert gas as the test medium.

(A)

Where this is not possible, the hose assembly shall be completely isolated from the system and tested with the flammable gas normally within the system,or with air and then purged with an inert gas.

(B)

In the case of hydrogen, testing shall be carried out with helium or a helium inert gas blend (10 percent by volume [helium] or greater) as the test gas or, ifthis is not possible, with hydrogen

using hydrogen using precautions.

11.2.14.8.4 Hose Protection.

When not in use, hose shall be secured to protect it from damage.

11.2.14.8.5 Hose Assemblies.

Listed hose assemblies shall be used to dispense fuel. Hose length at automotive motor fuel dispensing facilities shall not exceed 18 ft (5.5 m). [30A:12.2.4]


Systems leak on hydrogen that do not leak on other fluids. How do we test at temperature? The tests above are room temperature gas tests not cryo-hydrostatic tests. With the exception of helium all other gases are solids at liquid hydrogen temperatures.




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11.3.1.1 System Component Qualifications.



(2) Pressure gauges


(4) Valves



(7) Electrical equipment used with LH2 systems




(11) Flow meters


ASME not NFPA purview, Historically, proprietary components with product safety listing fall under NFPA.




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Welding or brazing for the repair or alteration of an ASME pressure vessel shall comply with the documents under which the pressure vessel wasfabricated local requlations .


Repair of fielded hardware is not ASME. Local regulation will invoke the NBBI NBIC.




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11.3.1.5.1.5

Pressure relief valves protecting ASME pressure vessels shall be repaired, adjusted, and tested in accordance with the ASME Boiler and Pressure VesselCode local regulations .


Repair of fielded hardware is not ASME. Local regulation will cal out NBBI NBIC




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11.3.1.6.6 The hose shall be guarded to protect the operator and the general public for the extreme temperature of the fluid the hose contains.


We missed a big one here. Hot sweaty hands on a -400 F hose or fitting...




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11.3.1.10.2

This leak test shall be in addition to the ANSI/ ASME B31 .3, Process Piping, testing Coe for Pressure Piping testing required by 11.2.8.3.


ASME B31 section 1, 3, 8 and 12 could be used and get the same answer. Conduct a gross leakage test prior to testing on hydrogen.




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11.3.1.10.3

The assembly shall be leak tested using hydrogen or helium .


Helium might not leak, when hydrogen does.




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11.3.1.10.5

Pressure relief valves shall be tested at least at a frequency set by local regulation, lacking regulation test every 3 years.


Clarity




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11.3.1.12.1

Where the flow is away from the hose, a check valve the means for back flow prevention shall be permitted to be used as the shut-off valve.


Function not hardware. Stating hardware inhibits the development of new hardware designs.




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11.3.1.16.1.1

If the hydrogen is not odorized, the wording “HYDROGEN GAS DOES NOT HAVE A DISTINCTIVE ODOR” shall be added to the warning sign“Liquid Hydrogen is extremely cold. Insert OSHA “safety symbol”. Do not touch the liquid” .


Liquid hydrogen is not odorized, it is a cryogenic. Any odorant would be a solid.




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11.3.1.19 Dispensing Devices.

Dispensing devices for LH2 shall be listed or approved . [30A:12.2.3]


It will probably take two code cycles to get sufficient product listed. Currently, there is sufficient demand for the hardware by the market to amortize the cost of a product listed.




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11.3.2 Dispensing to the Public.

Indoor LH 2 fueling shall not be permitted.

11.3.2.1 Outdoors.

A facility in which LH2 pumping, gas processing, hydrogen generation equipment, storage, and dispensing equipment are sheltered by an enclosure that is

constructed as weather protection in accordance with Section 6.6 with a roof designed for ventilation and dispersal of escaped gas shall be considered tobe located outdoors.

11.3.2.2 Indoors

(Reserved)


Currently cities like New York have indoor gasoline dispensers located in underground parking facilities. Don’t preclude the approach, remain neutral.




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Indoor LH 2 fueling shall not be permitted. (Reserved)


Currently cities like New York have indoor gasoline dispensers located in underground parking facilities. Don’t preclude the approach, remain neutral.




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11.3.3.1.5

A vehicle fueling pad shall be provided in the area where vehicles are to be refueled. shall occur upon a fueling pad

11.3.3.1.5.1

The pad shall be constructed with a length and width to accommodate the types of vehicles to be fueled and to provide a surface under the fueling hose.

11.3.3.1.5.2

The vehicle fueling pad shall be of durable non-combustible construction like concrete construction .

(A)

Combustible materials including asphalt shall not be used for the construction of or surfacing of the fueling pad. (See 8.3.2.3.1.5 .)


Make the requirements clear.




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11.3.4.6.5

Each area where dispensing of LH2 in the open from a transport vehicle to a motor vehicle shall be provided with one or more listed fire extinguishers that

have a minimum capability of 40 80 -B:C.

11.3.4.6.5.1

The fire extinguishers shall be within the dispensing operation.

11.3.4.6.5.2

Fire extinguishers shall be inspected and maintained under NFPA 10.


This paragraph addresses dispensing liquid hydrogen which is more hazardous than gaseous hydrogen thus the 40-B rating. There should be a larger extinguisher with more fire fighting capability. A 40-B extinguisher today is a 5 pound ABC with duration of approximately 14 seconds, which is a relatively very short duration. A 20 pound extinguisher will have a longer discharge duration (somewhere between 24 and 30 seconds, depending on the rating) and still has a good B:C rating.



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Chapter 12 Hydrogen Fuel Cell Fueled Power Systems

12.1 Scope.

This chapter shall apply to the design, construction, and installation of fuel cell fueled power systems.

12.1.1 Application.

The requirements of this chapter shall apply to stationary portable and micro fuel cell power generation systems.

12.1.1.1

The storage, use, and handling of hydrogen in any quantity shall also comply with the requirements of Chapters 1 through 4 and the applicablerequirements of Chapters 5 through 8.

12.1.1.2

Chapters 4 and 6 through 8 contain fundamental requirements that shall apply to all hydrogen systems.

12.1.1.2.1

The use-specific requirements of this chapter for hydrogen fuel cell power systems shall apply.

12.1.1.2.2

Where there is a conflict between a fundamental requirement and a use-specific requirement, the use-specific requirement shall apply.

12.2* General.

12.2.1* Listed and Approved Equipment.

12.2.1.1

Listed and approved hydrogen fuel cell equipment shall be installed in accordance with the listing requirements and manufacturers’ instructions.

12.2.1.2

Such equipment shall not be required to meet the requirements of Chapter 7.

12.3 Specific Requirements.

12.3.1 Stationary Fuel Cells.

12.3.1.1 General. [853:4.1]

12.3.1.1.1 Prepackaged, Self-Contained, Fuel Cell Power Systems. [853:4.2]

12.3.1.1.1.1

Prepackaged, self-contained [stationary] fuel cell power systems shall be designed, tested, and listed in accordance with ANSI CSA FC.1, AmericanNational Standard for Fuel Cell Power Systems. [853:4.2.1]

12.3.1.1.1.2

Prepackaged, self-contained [stationary] fuel cell power systems outside the scope of ANSI CSA FC.1, American National Standard for Fuel Cell PowerSystems, shall meet the provisions of 12.3.1.1.2 [853:4.2.2]

12.3.1.1.2 Pre-Engineered Fuel Cell Power Systems. [853:4.3]

12.3.1.1.2.1

Pre-engineered fuel cell power systems and matched modular components shall be designed and tested to meet the intent of ANSI CSA FC.1, AmericanNational Standard for Fuel Cell Power Systems. [853:4.3.1]

12.3.1.1.2.2

Proprietary equipment or materials for which no generally recognized codes or standards exist shall be evaluated based on data from operationalexperience in the same or comparable service or test records covering the performance of the equipment or materials. [853:4.3.2]

12.3.1.1.3 Engineered and Field-Constructed Fuel Cell Power Systems. [853:4.4]

12.3.1.1.3.1

Documentation for engineered and field-constructed fuel cell power systems shall be provided. [853:4.4.1]

12.3.1.1.3.2

Documentation shall include a fire risk evaluation prepared by a registered engineer or third party acceptable to the authority having jurisdiction. [853:4.4.2]

12.3.1.2 Siting and Installation.

12.3.1.2.1 Siting.

Stationary fuel cell power system(s) and associated equipment, components, and controls shall be sited and installed in accordance with NFPA 853.

12.3.2 Portable Fuel Cells.

12.3.2.1 General.

12.3.2.1.1*

Prepackaged, self-contained portable fuel cell power systems shall be designed, tested, and listed in accordance with ANSI/CSA FC 3, American NationalStandard / CSA American Standard for Portable Fuel Cell Power Systems, or IEC 6228-1, Portable Fuel Cell Power Systems, Safety .

12.3.2.2 Indoor Portable Fuel Cells. (Reserved)

12.3.2.3 Outdoor Portable Fuel Cells. (Reserved)

12.3.3 Micro Fuel Cells Power Systems.

12.3.3.1 General.


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12.3.3.1.1 Listed or Approved Systems.

Prepackaged, self-contained micro fuel cell power systems shall be listed or approved for the application.

12.3.3.2 Indoor Micro Fuel Cells. (Reserved)

12.3.3.3 Outdoor Micro Fuel Cells. (Reserved)

12.

4 Storage.

12.4.1 Requirements for Hydrogen Storage Systems Serving Stationary Fuel Cell Installations.

12.4.1.1

Storage systems serving stationary fuel cell power systems shall be in accordance with NFPA 853.

12.4.2 Requirements for Hydrogen Storage Systems Serving Portable Fuel Cell Power Systems.

12.4.2.1 General.

12.4.2.1.1 Fuel Cell Cartridges.

12.4.2.1.1.1 Listed or Approved Devices.

Fuel cell cartridges shall be listed or approved for the application.

12.4.2.1.1.2

Fuel cell cartridge refilling equipment shall be listed or approved for the application, and refill shall be in accordance with the manufacturer’s publishedinstructions and the listing.

12.4.2.2 Indoor Storage. (Reserved)

12.4.2.3 Outdoor Storage. (Reserved)

12.4.3 Requirements for Hydrogen Storage Systems Serving Micro Fuel Cell Power Systems.

12.4.3.1 General.

12.4.3.1.1 Fuel Cell Cartridges.

12.4.3.1.1.1 Listed or Approved Devices.

Fuel cell cartridges shall be listed or approved for the application.

12.4.3.1.1.2

Fuel cell cartridge refilling equipment shall be listed or approved for the application, and refill shall be in accordance with the manufacturer’s publishedinstructions and the listing.



3.3.4 Stationary Combustion Engines and Gas Turbine Generators

12.3.3.4.1 Prepackaged, Self-Contained, Internal Combustion Generators. Prepackaged, self-contained [stationary] fuel cell power systems shall bedesigned, tested, and listed in accordance with UL 2200, Stationary Engine Generator Assemblies.

12.3.3.4.2 Siting. Stationary fuel cell power system(s) and associated equipment, components, and controls shall be sited and installed in accordancewith NFPA 37 Standard for the Installation and Use of Stationary Combustion Engines and Gas Turbines.


Title and 12.1 change allows for H2 ICEs. and turbines. 12.3.2.1.1. deletes a non-ANSI reference.12.3.3.4 .Calls out NFPA 37 and UL2200 to cover turbines and ICEs.12.4 Was deleted. It is redundant with earlier chapters (storage).




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12.3.1.1.1.1

Prepackaged, self-contained [stationary] fuel cell power systems shall be designed, tested, and listed in accordance with ANSI CSA FC . 1, AmericanNational Standard for Fuel Cell Technologies - Part 3-100: Stationary Fuel Cell Power Systems - Safety . [853:4.2.1]


Correction to CSA Standard designation and title.




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12.3.1.1.1.2

Prepackaged, self-contained [stationary] fuel cell power systems outside the scope of ANSI/ CSA FC . 1, American National Standard for Fuel Cell PowerSystems Fuel cell technologies - Part 3-100: Stationary fuel cell power systems - Safety , shall meet the provisions of 12.3.1.1.2 [853:4.2.2]






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12.3.1.1.2.1

Pre-engineered fuel cell power systems and matched modular components shall be designed and tested to meet the intent of ANSI/ CSA FC . 1, AmericanNational Standard for Fuel Cell Power Systems Fuel cell technologies - Part 3-100: Stationary fuel cell power systems - Safety . [853:4.3.1]






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12.3.2.1.1*

Prepackaged, self-contained portable fuel cell power systems shall be designed, tested, and listed in accordance with ANSI/CSA America FC 3, AmericanNational Standard / CSA American Standard for Portable Fuel Cell Power Systems, or IEC 6228-1, Portable Fuel Cell Power Systems, Safety.






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12.3.3.4 Stationary Combustion Engines and Gas Turbine Generators

12.3.3.4.1 Prepackaged, Self-Contained, Internal Combustion Generators. Prepackaged, self-contained [stationary] fuel cell power systems shall bedesigned, tested, and listed in accordance with UL 2200, Stationary Engine Generator Assemblies.

12.3.3.4.2 Siting. Stationary fuel cell power system(s) and associated equipment, components, and controls shall be sited and installed in accordance withNFPA 37 Standard for the Installation and Use of Stationary Combustion Engines and Gas Turbines


nOW THR CHAPTER COVERS ALL HYDROGEN POWERED ELECTRIC GENERATORS, REGARDLESS OF TECHNOLOGY.




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13.3.1 Electrolyzers.

13.3.1.1 General.

13.3.1.1.1 Siting and Interconnecting.

Siting and interconnection of water electrolyzers shall be in accordance with the applicable requirements of Section 13.2 as modified or appended by thissection.

13.3.1.1.2* Product Standards.

Water electrolyzers shall be listed or approved for their use.

13.3.1.1.3 Hazardous Material Containment.

With the exception of gaseous hydrogen, electrolyzers that contain or utilize hazardous materials as defined by the adopted building code shall be designedand installed to contain such materials in accordance with the adopted building code.

13.3.1.2 Ventilation for Indoor Electrolyzers.

If mechanical ventilation is required, a control interlock shall be provided to shut down the electrolyzer upon loss of ventilation.

13.3.1.3

If oxygen is released within the electrolyzer room, sufficient ventilation shall be provided to prevent oxygen-enriched atmospheres above 23.5 percentoxygen.

13.3.1.4

Ventilation for indoor electrolyzers shall be in accordance with manufacturer's installation instructions and with one of the following:

(1) In accordance with Section 6.17.

(2) Use of constant ventilation sufficient to maintain an average H2 gas concentration within the room below 25 percent LFL based on the maximumanticipated hydrogen leak as determined by the manufacturer's installation instructions.

(3) Use of a hydrogen detection system, using GH2 detection equipment per Section 6.12, that initiates ventilation per Section 6.17 at a detected level of10 percent 25 percent LFL.

13.3.1.5 Indoor Installations of Electrolyzers.

13.3.1.5.1* Residential.

Electrolyzers listed or approved for residential occupancies compliant with the GH2 content limit of 6.4.1.5.1.1 shall be permitted.

13.3.1.6 Outdoor Installations of Electrolyzers. (Reserved)

Until a specific installation standard is generated, follow the appricable requirements in NFPA 853.


13.3.1.4 Why are we requiring 10 and 25% LFL instead of 25 and 50%? This isn’t a hydrocarbon fuel where the LFL and LEL are essentially the same.

13.3.1.6 I would expect that the requirements in NFPA 853 would suffice. Fuel cell is electrolyzer in reverse – power, water, hydrogen, and oxidant (air or oxygen).




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13.3.2.1.1.1

Hydrogen piping, valves, and fittings from the catalytic reforming–based hydrogen generation equipment to hydrogen storage system shall conform toASME /ANSI B31.12, Hydrogen Piping and Pipelines . B31 Code for Pressure Piping


This is a blanket change. Multiple sections of the code could be followed. Allow the user to use the same section throughout the product.




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13.3.2.2.7 Ventilation.

13.3.2.2.7.1

Catalytic reforming–based hydrogen generation systems shall be provided with a source of ventilation, in accordance with Section 6.17 and this chapter.

13.3.2.2.7.2

If mechanical ventilation is required, a control interlock shall be provided to shut down the unit upon loss of ventilation.

13.3.2.2.7.3 Ventilation Air.

(A)

If mechanical ventilation is required, a separate mechanical ventilation system shall be provided for the area where the catalytic reforming–based hydrogengeneration system power is located.

(B)

If natural ventilation is available, it shall be permitted to provide all required ventilation.

(C)

The air inlets shall be designed to prevent foreign matter from entering.












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13.3.2.3.2 Exhaust Outlets.

(A)

The exhaust outlet(s) from process areas or areas that contain fuel-bearing components of a catalytic reforming system shall be located at least 15 m(50 ft) from HVAC air intakes, windows, doors, and other openings into buildings, or in accordance with 7.3.2.3 .

(B)

Hydrogen generation system ventilation outlets that exhaust flammable gas in concentration exceeding 25 percent of the lower LEL shall not be directedonto walkways or other paths of travel for pedestrians.

(C)

Reformer burner exhausts shall be located and installed in accordance with Chapter 12 of NFPA 54.











Affilliation: Quong & Associatres, Inc./Toyota USA

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13.3.2.3.3

Air intakes to a hydrogen generation system shall be located so the plant is not adversely affected by other exhausts, gases, or contaminants.




This proposal is intended to correlate the various exhaust ventilation requirements by adding some of the later design material to Section 6.17 to enhance the core design parameters, adding pointers to Section 6.17 where lacking, deleting overlapping or otherwise unnecessary language and leaving additional requirements specific to the type of system ventilated in those areas of NFPA 2







Affilliation: Quong & Associates, Inc.,/Toyota USA

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13.3.2.4.1 General.

Subsection 13.3.2.4 identifies additional requirements and or modifications to 13.3.2 for small catalytic reforming hydrogen generation systems withhydrogen generation capacity of less than 9 lb/hr (4 kg/hr).

(Reserved)


There are no requirements in this section. Delete text and insert "Reserved"




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13.3.3.1.2.7 Warning Signals.

(A)

Warning signals (strobes and rotating lights) shall be provided at all gasifier hazard area access points.

(B)

These signals shall be tied to the detection systems outlined in 13.3.3.1.2.10 to warn of hazardous conditions.


Why are we requiring warning alarms for gasifiers? SMRs don’t require them and they generate CO and can generate carbonyls? Warning lights are usually used with attended equipment. In this context the equipment is is unattended, who will check the lights?

Delete.




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13.3.3.1.2.8

The controller for the gasifier process control system shall be located in a

safearea not accessible to the general public , isolated from the gasifier hazard area and other local hazards . A manually activated emergency stop deviceshall be located outside of the gasifier hazard area and be readily accessible to the owner/operator.


What does safe mean? Where is the manual e-stop?




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(A)

Piping, valves, and fittings from the gasifier chamber to the end use or storage system shall conform to ASME /ANSI B31.3, Process B31 Code forPressure Piping .


Blanket change




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(C)*

Thermal Detectors.

(1) Thermal detectors, thermal fuses and/or thermal cut-outs shall be provided throughout the gasifier area to detect fires and activate the firesuppression system and initiate a gasifier shutdown. These devices shall be listed, registered or approved.

(2) The detection system shall comply with NFPA 72.

(3) Ultraviolet/infrared (UV/IR) flame detection shall be provided in the vicinity of the gasifier vessel and all downstream equipment in which the gastemperature exceeds 80 percent of the lowest autoignition temperature of a contained constituent that exceeds 3 percent of the gas mix by volume.


These components are test to the following standards: UL 873 and UL 60730




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(C)*

Thermal Detectors.

(1) Thermal detectors shall be provided throughout the gasifier area to detect fires and activate the fire suppression system and initiate a gasifiershutdown.

(2) The detection system shall comply with NFPA 72.

(3) Ultraviolet/infrared (UV/IR) flame detection shall be provided in the vicinity of the gasifier vessel and all downstream equipment in which the gastemperature exceeds 80 percent of the lowest autoignition temperature of a contained constituent that exceeds 3 percent of the gas mix by volume.


We don’t care how, leave that to the designer. We care that it is detected. Function instead of hardware.




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13.3.3.2.2

Security barriers, fences, landscaping, or other obstacles shall be provided in the vicinity of the relief panels to prevent access to the potentially hazardousoutlet areas.


Move to 13.3.3.3. Security barriers fences landscaping inside???




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13.3.3.3 Outdoor Installations of Gasifiers.

The area containing the gasifier and associated conditioning equipment shall be located such that HVAC air intakes, windows, doors, and other openingsinto buildings cannot be exposed to the following:

(1) Hazardous atmospheres

(2) Toxic gases in excess of applicable OSHA exposure limits

(3) Security barriers, fences, landscaping, or other obstacles shall be provided in the vicinity of the relief panels to prevent access to the potentiallyhazardous outlet areas.


Moved from 13.3.3.2.2




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13.4 Storage.

13.4.1 Requirements for Hydrogen Storage Systems Serving Electrolyzer Installations.

The requirements of this section addressing hydrogen storage systems serving electrolyzer installations are supplemental to those specified bySection 13.2 and 13.3.1 .

13.4.1.1

In residential applications, the electrolyzer installation shall be in accordance with the equipment listing and the manufacturer's instructions.

13.4.1.2

Hydrogen piping, valves, and fittings from the electrolyzer to the hydrogen storage system shall be in accordance with ASME B31.12, Hydrogen Piping andPipelines .


Storage is previously address. Separate sections will lead to divergence in requirements.




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13.4.1 Requirements for Hydrogen Storage Systems Serving Electrolyzer Local Generation Installations.

The requirements of this section addressing address hydrogen storage systems serving electrolyzer installations are supplemental to those specified bySection 13.2 and 13.3.1 . local generation installations

13.4.1.1

In residential applications, the electrolyzer local generation installation shall be in accordance with the equipment listing and the manufacturer'sinstructions.

13.4.1.2

Hydrogen piping, valves, and fittings from the electrolyzer to the hydrogen storage system shall be in accordance with ASME B31 .12, Hydrogen Pipingand Pipelines . Code for Pressure Piping


Why is this limited to electrolyzers? What about reformers (SMR and ATR)? What about gasifiers? This should cover all H2 generators.

Reference the whole piping code, not just one section.




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14.3.1.2* Indoor Installations of Thermal Spraying Equipment.

14.3.1.2.1*

Thermal spray equipment shall be installed, inspected, and maintained in accordance with the manufacturer’s instructions to minimize the potential for leaksof the gas delivery system.

14.3.1.2.2*

The area in which the thermal spray equipment is installed shall be classified in accordance with NFPA 70, Article 500.

14.3.1.2.2.1

Electrical equipment comply with the requirements of NFPA 70 for the electrical classification of the area in which it is installed.

14.3.1.2.3

The area containing the thermal spray equipment shall be ventilated to prevent flammable gas buildup from potential system leaks.

14.3.1.2.3.1

Mechanical exhaust ventilation systems required by Section 6.17 or for operation of the equipment shall be interlocked with the thermal spraying equipmentto prevent the flow of gases without the ventilation system operating.

14.3.1.2.4*

The ceiling of rooms in which thermal spray equipment is installed shall be constructed in a manner to prevent the accumulation of hydrogen gas.

14.3.1.2.5

Venting systems discharging hydrogen to the atmosphere shall be piped to a designated point outside the building in accordance with Section 6.16.

14.3.1.2.6*

A hydrogen gas detection system shall be installed in the Hydrogen leak detection is required for a room or area where thermal spray equipment utilizinghydrogen gas is installed.

14.3.1.2.6.1

Activation of the gas detection system shall result in the following:

(1) The thermal spraying system shall be prevented from starting if hydrogen is detected at a concentration exceeding 25 percent LFL.

(2) The thermal spray system shall be shut down upon detection of hydrogen during operation at a concentration exceeding 25 percent LFL.

14.3.1.2.7

Automatic emergency shutoff valves shall be provided on the piping used to supply hydrogen gas to the thermal spraying equipment. Activation of thevalves shall shut off the flow of hydrogen in the event of the following:

(1) Loss of ventilation systems required by 14.3.1.2.3.1

(2) Detection of hydrogen at a concentration exceeding 25 percent LFL

(3) Activation of emergency stop functions provided with the manufacturer’s equipment


First - Is there enough radiant heat to do thermal spraying using hydrogen?

Second, 14.3.1.2.6 Mandate the requirement not the one method of meeting the requirement.




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The area in which the thermal spray equipment is installed shall be classified in accordance with NFPA 70, Article 500 or Article 505 .


The NFPA 70 Article 505 reference is being added to raise awareness of the alternate IEC information provided by Article 505. This makes NFPA 2 more universal and applicable in countries that subscribe to the IEC classification methods.







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14.4 Storage.

14.4.1 Requirements for Hydrogen Storage Systems Serving Thermal Spray Equipment.

14.4.1.1 General.

Hydrogen storage systems attendant to thermal spraying facilities shall be in accordance with the applicable requirements of Chapters 6 through 8.

14.4.1.1.1

Active gas generation devices used as a source of hydrogen supply, including but not limited to electrolyzers or reformers, shall also be in accordance withthe applicable provisions of Chapter 13.



14.4.2 Requirements for Hydrogen Storage Systems Serving Heating Applications. (Reserved)


This is the second chapter with storage. Why doesn’t this point back to chapters 4 & 6?

Why is 14.4.1.1.1 in storage?




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Chapter 15 Special Atmosphere Applications

15.1 Scope.

This chapter shall apply to equipment that uses hydrogen as an atmosphere for use in the following applications:

(1) Furnaces regulated by NFPA 86 using hydrogen in special atmosphere applications

(2) Hydrogen used as a heat exchange medium for hydrogen cooled electrical generators

15.1.1

The storage, use, and handling of GH2 in any quantity shall also comply with the requirements of Chapters 1 through 4 and the requirements of Chapters 6

through 8, as applicable.

15.1.2

In addition to the requirements of this code, furnaces using hydrogen in the form of a special atmosphere shall be in accordance with NFPA 86.

15.1.3


15.2 General. (Reserved)

15.3 Use.

15.3.1 Furnaces.

15.3.1.1 General.

15.3.1.1.1*

Subsection 15.3.1 shall apply to the production and use of special atmospheres either by blending (or mixing) pure hydrogen gas with other gases, suchas nitrogen or the use of pure hydrogen as the sole constituent of the special atmospheres in furnaces.

15.3.1.1.1.1

Subsection 15.3.1 shall apply to special atmospheres containing hydrogen used in Class C or Class D furnaces.

15.3.1.1.1.2

All furnace installations shall also comply with the requirements of NFPA 86.

15.3.1.1.2

Before new equipment is installed or existing equipment is remodeled, complete plans, sequence of operations, and specifications shall be submitted forapproval to the authority having jurisdiction. [86:4.1.1]

15.3.1.1.2.1*

Plans shall be drawn that show all essential details with regard to location, construction, ventilation, piping, and electrical safety equipment. A list of allcombustion, control, and safety equipment giving manufacturer and type number shall be included. [86:4.1.1.1]

15.3.1.1.2.2*

Wiring diagrams and sequence of operations for all safety controls shall be provided. [86:4.1.1.2]

15.3.1.1.2.3

Any deviation from this code shall require approval from the authority having jurisdiction. [86:4.1.2]

15.3.1.1.3 Venting.

15.3.1.1.3.1

Unwanted, normal operating, and emergency releases of fluids (gases or liquids) from special [hydrogen] atmosphere generators, storage tanks, gascylinders, and flow control units shall be disposed of to an approved location. [86:13.5.1.3]

15.3.1.1.3.2

Venting of unwanted flammable [hydrogen] atmosphere gas shall be done by controlled venting to an approved location outside the building or bycompletely burning the atmosphere gas and venting the products of combustion to an approved location. [86:13.5.1.4]

15.3.1.1.3.3

Nonflammable and nontoxic fluids shall be vented to an approved location outside the building at a rate that does not pose a hazard of asphyxiation.[86:13.5.1.5]

15.3.1.1.4 Flow Control of Special [Hydrogen] Atmospheres. [86:13.5.7]

15.3.1.1.4.1*

Processes and equipment for controlling flows of special [hydrogen] atmospheres shall be designed, installed, and operated to maintain a positivepressure within connected furnaces. [86:13.5.7.1]

15.3.1.1.4.2

The flow rates used shall restore positive internal pressure without infiltration of air during atmosphere contractions when furnace chamber doors close orworkloads are quenched. [86:13.5.7.2]

15.3.1.1.4.3*

Where the atmosphere is flammable, its flow rate shall be sufficient to provide stable burn-off flames at vent ports. [86:13.5.7.3]

15.3.1.1.4.4

Means shall be provided for metering and controlling the flow rates of all fluids that the special [hydrogen] atmosphere for a furnace comprises.[86:13.5.7.4]


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(A)

Devices with visible flow indicators shall be used to meter the flows of carrier gases, carrier gas component fluids, inert purge gases, enrichment gases, orair. [86:13.5.7.4 (A)]

(B)

The installation of flow control equipment shall meet the following criteria: [86:13.5.7.4 (C)]

(1) It shall be installed at the furnace, at the generator, or in a separate flow control unit. [86:13.5.7.4 (C)(1)]

(2) It shall be accessible and located in an illuminated area so that its operation can be monitored. [86:13.5.7.4 (C)(2)]

15.3.1.1.5* Special Processing Hydrogen Atmosphere Gas Mixing Systems.

Where [hydrogen atmospheres are prepared using] gas mixing systems that incorporate a surge tank mixing scheme that cycles between upper and lowerset pressure limits, the following shall apply:

(1)

(2) The effluents from the relief devices used to protect a [hydrogen] atmosphere mixing system shall be piped to an approved location.

(3)

(4) The use of liquids shall not be permitted in [hydrogen] atmosphere mixing systems.

(5) Means shall be provided for metering and controlling the flow rates of all gases.

(6) Flow control of the blended atmosphere gas shall be in compliance with each furnace's applicable special [hydrogen] atmosphere flow requirementsand protective equipment.

(7) Atmosphere gas mixers that create nonflammable or indeterminate gas mixtures shall be provided with the following:

(a) Gas analyzers or other equipment for continuously monitoring and displaying the flammable gas composition

(b) Automatic controls to shut off the flammable gas flow when the [hydrogen] concentration rises above the operating limit

(8) If the creation of a gas mixture with a [hydrogen] content that is higher than intended results in the risk of explosions where none existed, controls shallbe provided to shut off the [hydrogen] flow automatically when the [-] concentration rises above the operating limit.

(9) When the [hydrogen] concentration in a mixed gas exceeds the established high limit, an alarm shall be actuated to alert personnel in the area.

(10) Restart of [hydrogen] flow after a high concentration limit interruption shall require manual intervention at the site of the gas mixer.

(11) Safety shutoff valves used to admit combustible gases to the gas mixer shall be normally closed and capable of closing against maximum supplypressure.

(12) Atmosphere gas mixers installed outdoors shall be selected for outdoor service or placed in a shelter that provides weather protection.

(13) Where a gas mixer is sited in a shelter, the temperature within shall be maintained in accordance with the manufacturer's recommendations.

[86:13.5.6]

15.3.1.1.6 Synthetic Atmosphere Flow Control.

Synthetic atmosphere flow control units shall have the additional capabilities specified in 15.3.1.1.6.1 through 15.3.1.1.6.9. [86:13.5.8]

15.3.1.1.6.1

An atmosphere flow control unit equipped with an inert purge mode shall have a manually operated switch on the face of the unit that actuates the purge.[86:13.5.8.1]

15.3.1.1.6.2

A safety interlock shall be provided for preventing the initial introduction of [any] flammable fluid into a furnace before the furnace temperature has risen to1400°F (760°C). [86:13.5.8.2]

(1) Open circuit failure of the temperature-sensing components shall cause the same response as an operating temperature less than 1400°F (760°C).[86:8.17.2]

(2)

(3)

(4) The temperature-sensing element of the 1400°F (760°C) bypass interlock shall be located so that unsupervised burners are not allowed to operate attemperatures below 1400°F (760°C). [86:8.17.5]

(5)

(6)

(7) Visual indication shall be provided to indicate when the 1400°F (760°C) bypass interlock is in the bypass mode. [86:8.17.7]

(8)

15.3.1.1.6.3

Resumption of [hydrogen atmosphere] flow following a power failure shall require manual intervention (reset) by an operator after power is restored.[86:13.5.8.5]

15.3.1.1.6.4

Where the flammable fluid flow is interrupted, one of the following shall apply:

(1) The flow control unit shall automatically admit a flow of inert gas that restores positive pressure and shall initiate an audible and visual alarm, unlessotherwise permitted by 15.3.1.1.6.4(2).

(2) Manual inert gas purge shall be provided for furnaces where operators are present and able to effect timely shutdown procedures subject to theauthority having jurisdiction.

[86:13.5.8.6]

* Pipes feeding [hydrogen] atmosphere mixing systems shall contain manual isolation valves.

* Piping and components shall be in accordance with ASME B31.1, appropriate volume.

* The 1400°F (760°C) bypass interlock shall be equipped with temperature indication. [86:8.17.3]

* The temperature-sensing components of the 1400°F (760°C) bypass interlock shall be rated for the temperature and the atmosphere to which theyare exposed. [86:8.17.4]

* The temperature-sensing element of the [1400°F (760°C)] bypass interlock shall be located where recommended by the [furnace] manufacturer ordesigner. [86:8.16.8]

* The 1400°F (760°C) bypass interlock set point shall not be set below 1400°F (760°C) and shall indicate its set point in units of temperature (degreesFahrenheit or degrees Celsius) that are consistent with the primary temperature-indicating controller. [86:8.17.6]

* The operating temperature interlock and its temperature-sensing element shall not be used as the 1400°F (760°C) bypass interlock. [86:8.17.8]


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15.3.1.1.6.5

Means shall be provided to test for leak-free operation of safety shutoff valves for flammable or toxic fluids. [86:13.5.8.7]

15.3.1.1.6.6*

Safety relief valves to prevent overpressurizing of glass tube flowmeters and all other system components shall be in accordance with ASME B31.1,appropriate volume. [86:13.5.8.8]

15.3.1.1.6.7

The effluents from relief valves used to protect control unit components containing flammable or toxic fluids shall be piped to an approved disposallocation. [86:13.5.8.9]

15.3.1.1.6.8

Alternative valves meeting the following criteria shall be provided for manually shutting off the flow of flammable fluids into a furnace: [86:13.5.8.10]

(1) They shall be separate from the atmosphere control unit. [86:13.5.8.10(1)]

(2) They shall be accessible to operators. [86:13.5.8.10(2)]

(3) They shall be located remotely from the furnace and control unit. [86:13.5.8.10(3)]

(4) They shall be listed or approved for the service.

15.3.1.1.6.9*

Pipes feeding atmosphere flow control units shall contain isolation valves. [86:13.5.8.11]

15.3.1.1.6.10

Low melting point solder shall not be used with piping supplying hydrogen to furnaces or to special [hydrogen] atmosphere blending systems of flowcontrol manifolds.

15.3.1.1.7 Piping Systems for Hydrogen Atmospheres.

15.3.1.1.7.1

Piping shall be sized for the full flow of [hydrogen] atmospheres to all connected furnaces at maximum demand rates. [86:13.5.9.1]

15.3.1.1.7.2*

Pressure vessels and receivers shall be constructed of materials compatible with the lowest possible temperature of [hydrogen] processing atmospheres,or controls shall be provided to stop the flow of gas when the minimum temperature is reached. [86:13.5.9.2]

(A)

A low temperature shutoff device used as prescribed in 15.3.1.1.7.2 shall not be installed so that closure of the device can interrupt the main flow of inertsafety purge gas to connected furnaces containing indeterminate special processing atmospheres. [86:13.5.9.2(A)]

(B)

If closure of a low temperature shutoff device creates any other hazard, an alarm shall be provided to alert furnace operators or other affected persons ofthis condition. [86:13.5.9.2(B)]

(C)

The user shall consult with the industrial gas supplier to select the low temperature shutoff device, its placement, and a shutoff set point temperature.[86:13.5.9.2(C)]

15.3.1.1.8 Inspection, Testing, and Maintenance.

15.3.1.1.8.1

All safety interlocks shall be tested for function at least annually. [86:7.4.4]

15.3.1.1.8.2*

The set point of temperature, pressure, or flow devices used as safety interlocks shall be verified at least annually. [86:7.4.5]

15.3.1.1.8.3

Safety device testing shall be documented at least annually. [86:7.4.6]

15.3.1.1.8.4

Whenever any safety interlock is replaced, it shall be tested for function. [86:7.4.16]

15.3.1.1.8.5

Whenever any temperature, pressure, or flow device used as a safety interlock is replaced, the set point setting shall be verified. [86:7.4.17]

15.3.1.1.9 Fire Protection.

15.3.1.1.9.1* General.

A study shall be conducted to determine the need for fixed or portable fire protection systems for ovens, furnaces, or related equipment. [86:9.1]

(A)

The determination of the need for fire protection systems shall be based on a review of the fire hazards associated with the equipment. [86:9.1.1]

(B)

Where determined to be necessary, fixed or portable fire protection systems shall be provided. [86:9.1.2]

15.3.1.1.10* Special Atmospheres and Furnaces.

15.3.1.1.10.1 Indeterminate Atmospheres.

Indeterminate atmospheres shall be treated as flammable atmospheres with the following considerations:

(1) Where one special atmosphere is replaced with another special atmosphere (e.g., flammable [hydrogen] replaced with nonflammable) that can causethe atmosphere to become indeterminate at some stage, burn-in or burn-out procedures shall not be used.

(2) In the case of any indeterminate atmosphere, inert gas purge procedures alone shall be used for introduction and removal of special processingatmospheres.

[86:13.5.10.1]


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15.3.1.1.10.2 Automatic Cycling.

Automatic cycling of a furnace (e.g., quenching, load transfer from a heated zone to a cold vestibule) shall not be permitted where the special atmospherehas become indeterminate during the replacement of a flammable [hydrogen] atmosphere with a nonflammable or an inert atmosphere (or vice versa) untilthe special atmosphere in all furnace chambers has been verified as either flammable, nonflammable, or inert. [86:13.5.10.2]

15.3.1.1.10.3* Furnace Type.

The type of furnace shall be determined in accordance with Table 15.3.1.1.10.3. [86:13.5.10.3]

Table 15.3.1.1.10.3 Types of Furnaces

FurnaceType Feature Operating Temperature Example

Type I The chamber(s) <1400°F are separatedby doors from those operating at >1400°F

One or more zones always >1400°FPusher tray (cold chambers at each end, innerand outer doors with and without integralquench)

Type II Can be <1400°F after introduction of a cold loadBatch integral quench (1 or more coldchambers, integral quench)

Type IIIBoth inlet and outlet ends of furnace areopen and no external doors or covers

At least one zone >1400°F and have no innerdoors separating zones > and <1400°F

Belt (both ends open)

Type IVOnly one end of the furnace is open andthere are no external doors or covers

Belt (with integral quench, entry end open)

Type V Outer doors or covers are provided Box (exterior door)

Type VI>1400°F before introduction and removal ofspecial [hydrogen] atmosphere gas

Type VII Never >1400°F

Type VIIIA heating cover furnace with an innercover A heating cover and inner cover are separated

from a base that supports the work beingprocessed

Bell (with or without retort)

Type IXA heating cover furnace without an innercover or with a nonsealed inner cover

Car tip-up

For SI units, 1400°F = 760°C.

[86: Table 13.5.10.3]

15.3.1.1.11 Design Requirements for the Introduction, Use, and Removal of Flammable and Indeterminate Special Atmospheres from Furnaces.[86:13.5.11.1]

15.3.1.1.11.1 General.

(A)

Flammable and indeterminate atmosphere gases shall be introduced, used, and removed from furnaces without creating an uncontrolled fire, deflagration,or explosion. [86:13.5.11.1(A)]

(B)*

Special atmosphere furnaces that use flammable [hydrogen] or indeterminate special atmospheres shall be designed and maintained to minimize theunintended infiltration of air into the furnace. [86:13.5.11.1(B)]

(C)*

Operating instructions for introducing, using, and removing flammable special [hydrogen] atmosphere gases shall comply with Chapter 15 and Section 7.3of NFPA 86. [86:13.5.11.1(C)]

(D)*

Where present, the liquid level in manometers or bubbler bottles on vent lines shall be checked and maintained at the required operating range asnecessary. [86:13.5.11.1(D)]

(E)*

Discharge from effluent vents of furnaces using special [hydrogen] atmospheres shall be piped or captured by hoods and discharged to an approvedlocation. [86:13.5.11.1(E)]

(F)*

Process control air or burnout air shall be supplied from an air blower. [86:13.5.11.1(F)]

15.3.1.1.11.2 Burn-Off Pilots and Other Ignition Sources. [86:13.5.11.2]

This section applies to burn-off pilots and other ignition sources provided for the purpose of igniting flammable special [hydrogen] atmosphere gases ateffluent stacks, open ends, or doors when a flammable atmosphere is present in the furnace. [86:13.5.11.2]

(A)

A burn-off pilot, glow plug, flame screen, or other source of ignition shall be provided and located at the gas–air interface and sized to reliably ignite theflammable special [hydrogen] atmosphere gas that is released at effluents, open ends or doors. [86:13.5.11.2(A)]

(B)*

Burn-off pilots that are exposed to inert purge gas or special [hydrogen] atmosphere gas under either normal or emergency conditions shall be of a typethat will remain in service to ignite flammable effluent gases. [86:13.5.11.2(B)]

(C)*

Burn-off pilots igniting effluent from vent pipes shall not require flame supervision. [86:13.5.11.2(C)]

(D)

Where burn-off pilots are the primary ignition source for effluent from open furnace ends, at least one burn-off pilot shall have flame supervision at eachopen end. [86:13.5.11.2(D)]

(E)*

Where one or more burn-off pilots are the primary ignition source at a door, at least one burn-off pilot shall have flame supervision interlocked to preventautomatic door opening in the event of flame failure. [86:13.5.11.2(E)]


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(F)

Burn-off pilots that have flame supervision shall accomplish the following:

(1) Provide an audible and visual alarm to alert the operator to the failure

(2) Not shut off the burn-off pilot gas in the event of flame failure

[86:13.5.11.2(F)]

(G)*

Burn-off pilot gas shall not shut off in the event of power failure. [86:13.5.11.2(G)]

(H)*

Burn-off pilots shall be located and sized to reliably ignite the effluent stream. [86:13.5.11.2(H)]

(I)

Each burn-off pilot shall be equipped with an individual manual shutoff valve. [86:13.5.11.2(I)]

(J)*

Burn-off pilots gas supply source shall be located downstream of the equipment main manual isolation valve and upstream of any other shutoff devicesthat can close automatically, including safety shutoff valves. [86:13.5.11.2(J)]

15.3.1.1.11.3* Flame Curtains.

Where a flame curtain is used, the following features shall be provided and in service:

(1) One or more flame curtain pilots shall be positioned to reliably ignite the flame curtain.

(2) At least one flame curtain pilot at a flame curtain shall have flame supervision interlocked to prevent the opening of a closed door served andinterlocked to prevent operation of the flame curtain at the door served.

(3) At least one safety shutoff valve upstream of all flame curtains on a furnace shall be interlocked to close upon the following conditions:

(a) Low fuel gas pressure on the flame curtain fuel gas supply

(b) High fuel gas pressure on the flame curtain fuel gas supply where a high gas pressure issue would create a safety concern

(4) An automatic control valve shall be provided ahead of each flame curtain arranged to open when the door served is not closed.

(5) When the safety shutoff valve in item 15.3.1.1.11.3(3) is closed, any doors served by that safety shutoff valve shall be interlocked so they cannotopen.

(6)

[86:13.5.11.3]

15.3.1.1.11.4 Flammable Special Atmosphere Introduction.

Flammable special [hydrogen] atmospheres shall be introduced into a furnace using one of the following methods:

(1) Purge-in

(2) Burn-in

[86:13.5.11.4]

15.3.1.1.11.5 Flammable Special Atmosphere Removal.

Flammable special [hydrogen] atmospheres shall be removed from a furnace using one of the following methods:

(1) Purge-out

(2) Burn-out

[86:13.5.11.5]

15.3.1.1.11.6 Purge-in Requirements.

(A)

Written purge-in instructions shall be provided for each furnace. [86:13.5.11.6.1]

(1)

(2) Furnace doors and covers shall be positioned in accordance with the operating instructions before purge-in begins. The inner and outer covers ofType VIII and Type IX furnaces shall not be placed in position onto the furnace base unless the workload and base are at least 50°F (28°C) below theauto-ignition temperature of any flammable gas mixture that can be present in the cover. [86:13.5.11.6.1(B)]

(B)

Purge-in shall reduce the oxygen content of the furnace to less than 1 percent by displacement with an inert gas or before introduction of the flammablespecial [hydrogen] atmosphere gas. [86:13.5.11.6.2]

(C) Positive Furnace Pressure.

(1) A positive furnace pressure shall be maintained during the purge-in process and continue through the transition from the inert gas purge to theintroduction of special [hydrogen] atmosphere gas. [86:13.5.11.6.3(A)]

(2) Positive pressure for Type VIII or Type IX heating-cover (retort) type furnaces shall be indicated by a bubbler, vent manometer, or similar device.[86:13.5.11.6.3(B)]

(D)*

During the inert gas purge, flammable special [hydrogen] atmosphere safety shutoff valves shall remain closed. [86:13.5.11.6.4]

(E)

Purging of the furnace shall continue until the purge has been verified as complete using one of the following methods:

(1) Time-flow purge method in accordance with Section 13.5.12 of NFPA 86.

(2) Two consecutive analyses of all chambers indicating that the oxygen content is less than 1 percent

[86:13.5.11.6.5]

* A manual means of overriding the door interlock in 15.3.1.1.11.3(5) shall be provided.

* Purge effectiveness shall not be compromised during the purge process. [86:13.5.11.6.1(A)]


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(F)

Furnaces shall not be required to be at any specific temperature when the inert gas is displaced by the flammable special [hydrogen] atmosphere gases.[86:13.5.11.6.6]

(G)*

Active sources of ignition shall be provided at interfaces between air and flammable or indeterminate special [hydrogen] atmosphere gases at furnaceopenings and doors. Effluent vents terminating inside a building shall also be provided with an active source of ignition. [86:13.5.11.6.7]

(H)*

All furnace and vestibule volumes that will contain a flammable special [hydrogen] atmosphere gas shall be purged with inert gas prior to the special[hydrogen] atmosphere gas being admitted. [86:13.5.11.6.8]

(I)

During the inert gas purge, all flame curtain fuel gas valves shall be closed. [86:13.5.11.6.9]

(J)

During the inert gas purge, all circulating and recirculating fans shall be operating as required by the operating instructions. [86:13.5.11.6.10]

(K)

Flammable special [hydrogen] atmosphere gases shall not be introduced unless the following conditions exist:

(1) Burn-off pilots at open ends, doors, and effluent lines are ignited.

(2) All manual valves to flame curtains (where provided) are open.

(3) All automatic valves to flame curtain are in service.

(4)

(5) Purging of the furnace has been completed as defined by 15.3.1.1.11.6(E)

(6) Operation of flame curtains (where provided) is verified.

[86:13.5.11.6.11]

(L)*

After the introduction of the flammable special [hydrogen] atmosphere, the purge-in atmosphere introduction process is considered complete when flameappears at furnace doors, open ends, or effluent lines in accordance with the specific design features and operating instructions for the furnace.[86:13.5.11.6.12]

15.3.1.1.11.7 Burn-in Requirements.

(A)

Written burn-in instructions shall be provided for each furnace. [86:13.5.11.7.1]

(1)

(2) The position of inner and outer furnace doors and the placement of manual torches shall be as directed in the operating instructions during each stageof the burn-in procedure. [86:13.5.11.7.1(B)]

(B)*

Burn-in shall reduce the oxygen content of the furnace by consuming the oxygen in the air through combustion with a flammable atmosphere gas that willreliably ignite at the gas–air interfaces. [86:13.5.11.7.2]

(C)*

To begin the burn-in process, the flammable special [hydrogen] atmosphere gas shall be introduced at a location in the furnace that is at or above 1400°F(760°C). [86:13.5.11.7.3]

(D)*

Where a stable flame front propagating through a chamber under 1400°F (760°C) cannot be maintained, the burn-in process shall not be used.[86:13.5.11.7.4]

(E)*

For zones under 1400°F (760°C), stable flames of burning gas shall be maintained in the zones as the special [hydrogen] atmosphere gas is burned-in.[86:13.5.11.7.5]

(F)*

For a Type II furnace (batch integral quench furnace) with heating chamber fan, the fan shall not be operating during burn-in while the inner heatingchamber door is open. [86:13.5.11.7.6]

(G)*

For Types I through VII furnaces, recirculating fans in cooling zones shall be turned off during burn-in. [86:13.5.11.7.7]

(H) Special Requirements for Type VIII and IX Furnaces.

(1) Circulating base fans, where provided, shall be turned on. [86:13.5.11.7.8(A)]

(2)

(3)

(I)

For Type VIII furnaces, atmosphere introduction shall be by purge-in, and atmosphere removal shall be by purge-out; burn-in and burn-out proceduresshall not be used. [86:13.5.11.7.9]

(J)*

After the introduction of the flammable special [hydrogen] atmosphere, the burn-in atmosphere introduction process shall be considered complete whenflame appears at the furnace doors, open ends, or effluent lines, where present, in accordance with the specific design features and operating instructionsfor the furnace. [86:13.5.11.7.10]

* All required quench fluid levels are at the correct level.

* Burn-in effectiveness shall not be compromised by taking any action that deviates from the written operating instructions for burn-in.[86:13.5.11.7.1(A)]

* The cover shall be sealed to the furnace base before flammable or indeterminate special [hydrogen] atmospheres are introduced. [86:13.5.11.7.8(B)]

* Where a furnace uses an oil seal between a cover and a base, means shall be provided so that furnace pressure is maintained below the static headpressure of the seal oil. [86:13.5.11.7.8(C)]


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15.3.1.1.11.8 Purge-out Requirements.

(A)

Written purge-out instructions shall be provided for each furnace. [86:13.5.11.8.1]

(1)

(2) Furnace doors and covers shall be positioned in accordance with the manufacturer’s instructions before purge-out begins. [86:13.5.11.8.1(B)]

(B) Positive Furnace Pressure.

(1) A positive furnace pressure shall be maintained at all times during purge-out, including the transition from the special [hydrogen] atmosphere gasoperation to the inert gas purge. [86:13.5.11.8.2(A)]

(2) For Types VIII and IX furnaces, an indication of positive furnace pressure shall be provided by an indicating manometer or similar device.[86:13.5.11.8.2(B)]

(C)*

Once the inert purge gas flow has been established for purge-out, the flow of all flammable special [hydrogen] atmosphere gases shall be stopped.[86:13.5.11.8.3]

(D)*

Purging shall include all of the furnace volume that contains a flammable or indeterminate special [hydrogen] atmosphere gas. [86:13.5.11.8.4]

(E)*

Purge-out shall be considered complete when all chambers that would create a hazard are below 50 percent of LFL and shall be determined by one of thefollowing two methods:

(1) Time-flow purge method in accordance with Section 13.5.12 of NFPA 86 as it applies to the purge-out process

(2) Two consecutive analyses of all chambers indicating that the flammable level within the furnace is below 50 percent of LFL

[86:13.5.11.8.5]

(F)

When purge-out is complete, the following shall be permitted to be turned off:

(1) Burn-off pilots

(2) Circulation and recirculation fans required for purge-out

(3) Inert purge gas supply to the furnace

(4) Flame curtains

[86:13.5.11.8.6]

15.3.1.1.11.9 Burn-Out Requirements.

(A)

Written burn-out instructions shall be provided for each furnace. [86:13.5.11.9.1]

(1)

(2)

(B)*

Through the controlled admission of air to a furnace, burn-out shall reduce the flammable content within all heating chambers and vestibules throughcombustion with the oxygen in the air. [86:13.5.11.9.2]

(C)*

To initiate the burn-out process, one of the following conditions shall be met:

(1) Air is introduced into the furnace at a point that is at or above 1400°F (760°C).

(2) Where air is introduced into a furnace at a point below 1400°F (760°C), the following shall apply:

(a)

(b) A source of ignition is provided at the interface between the flammable atmosphere and the point of air introduction.

[86:13.5.11.9.3]

(D)

Burn-out shall include turning off all special [hydrogen] atmosphere gases and admitting air in a sequence outlined in the written burn-out instructions.[86:13.5.11.9.4]

(E)

Burnout air shall be admitted by any of the following arrangements:

(1) Through furnace doors

(2) Through independent piping and furnace gas inlets

(3) Through sections of piping and furnace inlets that are common to both flammable special [hydrogen] atmosphere and burnout air when the systemsare designed to prevent the flow of air and flammable special [hydrogen] atmosphere at the same time

[86:13.5.11.9.5]

(F)*

During burn-out, recirculating fans shall be turned off in furnace zones under 1400°F (760°C) and in zones at or above 1400°F (760°C) that can causeturbulence in zones under 1400°F (760°C). [86:13.5.11.9.6]

* Purge effectiveness shall not be compromised during the purge process. [86:13.5.11.8.1(A)]

* Burn-out effectiveness shall not be compromised by taking any action that deviates from the written operating instructions for burn-out.[86:13.5.11.9.1(A)]

* Inner and outer furnace doors, where provided, shall be placed in the appropriate position as directed in the operating instructions during each stageof the burn-out procedure. [86:13.5.11.9.1(B)]

* The furnace is under positive pressure.


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(G)

Burn-out shall be considered complete when one of the following conditions is satisfied:

(1) For furnaces that do not contain soot, all visible flame in the furnace and at all effluents are observed to be extinguished.

(2) For furnaces that contain soot that cannot re-form a flammable atmosphere gas, all visible flames in the furnace and at all effluents are observed to beextinguished.

(3) For furnaces that contain soot that re-form flammable atmosphere gas, all visible flames in the furnace and at effluents are observed to beextinguished after burn-out procedures are performed that include the introduction of additional air to effect the burn-out of the re-formed flammableatmosphere gas.

[86:13.5.11.9.7]

(H)

When burn-out is complete, the following shall be permitted to be turned off:

(1) Burn-off pilots

(2) Circulation and recirculation fans required for burn-out

(3) Flame curtains

[86:13.5.11.9.8]

15.3.1.1.11.10* Special Atmosphere Equipment Piping System. [86:13.5.11.10]

(A) General.

The special [hydrogen] atmosphere equipment piping system shall be that piping starting at the equipment manual isolation valve that includes thecomponents for the delivery of special [hydrogen] atmosphere fluids to a furnace. [86:13.5.11.10.1]

(B) Manual Shutoff Valves and Equipment Isolation.

(1)

(2) The position of any manual shutoff valve that can interrupt the supply of inert gas to an automatic inert purge gas line shall be electrically supervisedand cause a visual and audible alarm to alert the operator whenever this valve is not in the open position and the automatic inert purge is required tobe in service. [86:13.5.11.10.2.2]

(3) A bypass manual shutoff valve shall be provided to bypass each normally open emergency inert gas purge valve, and be arranged as follows:

(a) Be accessible to the operator for use in accordance with written operating instructions

(b) Have a port area equal to or larger than the bypassed normally open emergency inert gas purge valve

[86:13.5.11.10.2.3]

(4) Each manual shutoff valve shall have a tag that identifies the valve and the special [hydrogen] atmosphere it controls. [86:13.5.11.10.2.4]

(5) The operating instructions required by Section 7.3.3 of NFPA 86 shall reference the valve tag identifications required by 15.3.1.1.11.10(B)(4).[86:13.5.11.10.2.5]

(6) Each manual shutoff valve (equipment isolation valve) shall be in accordance with the following: [86:13.5.11.10.2.6]

(a) They shall be provided for each piece of equipment.

(b) They shall have permanently affixed visual indication of the valve position.

(c) They shall be quarter-turn valves with stops.

(d) Wrenches or handles shall remain affixed to valves and shall be oriented with respect to the valve port to indicate the following:

i. An open valve when the handle is parallel to the pipe

ii. A closed valve when the handle is perpendicular to the pipe

(e) They shall be readily accessible.

(f) Valves with removable wrenches shall not allow the wrench handle to be installed perpendicular to the fuel gas line when the valve is open.

(g) They shall be able to be operated from full open to full close and return without the use of tools.

(7) Manual valves that are not used for shutoff shall not be required to comply with 15.3.1.1.11.10(B) other than 15.3.1.1.11.10(B)(4) . [86:13.5.11.10.2.7]

[86:13.5.11.10.2.3]

* An equipment isolation manual shutoff valve shall be provided for each special [hydrogen] atmosphere fluid, shall be located upstream of all deviceson the special [hydrogen] atmosphere equipment piping, and shall be lockable. [86:13.5.11.10.2.1]

(a) Where fuel gas is used as a special [hydrogen] atmosphere gas, a separate manual shutoff valve shall be provided for the special [hydrogen]atmosphere feed. This valve shall not be required to be lockable where the fuel gas main isolation manual shutoff valve is lockable.[86:13.5.11.10.2.1(A)]

(b) Equipment isolation manual shutoff valves for each special [hydrogen] atmosphere fluid shall be accessible from the normal operator workinglevel without the use of ladders or portable equipment. [86:13.5.11.10.2.1(B)]


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(C) Regulators.

(1) Regulators shall be provided on each special [hydrogen] atmosphere gas line where the gas supply pressure exceeds the operating or designparameters of equipment piping and components in the equipment piping. [86:13.5.11.10.3(A)]

(2)

(3) Regulator vents shall not be manifolded with the following:

(a) Vents from other furnaces

(b) Vents downstream of the safety shutoff valves

(c) Relief valve vents

[86:13.5.11.10.3(C)]

(4)

(5) The regulator vent termination shall be designed to prevent the entry of water and insects without restricting the flow capacity of the vent.[86:13.5.11.10.3(E)]

(D) Relief Valves.

(1)

(2)

(3)

(4) Relief valve piping shall not be manifolded with either of the following:

(a) Vents from other furnaces

(b) Vents from regulators

[86:13.5.11.10.4(D)]

(5) Relief valve piping shall not be manifolded with other relief valve piping where either of the following could occur: [86:13.5.11.10.4(E)]

(a) Mixing of liquids and gases [86:13.5.11

(b) Mixing of fluids (liquids or gases) that could result in corrosion to relief valves or relief valve piping [86:13.5.11]

(E) Filters.

(1) A filter shall be provided upstream of each liquid flow sensor. [86:13.5.11.10.5(A)]

(2) A filter shall have a particle size rating that will not allow particles of a size that can foul liquid flow sensors or liquid flowmeters to pass the filter.[86:13.5.11.10.5(B)]

(F) Flowmeters.

One flowmeter shall be provided on each special [hydrogen] atmosphere equipment supply line. [86:13.5.11.10.6]

(G) Pressure Gauges.

Pressure gauges shall be provided at points in the special [hydrogen] atmosphere equipment piping where the operator must be provided visual pressureinformation to verify the furnace is being maintained within safe operating limits. These points shall be determined as part of the furnace design.[86:13.5.11.10.7]

(H)* Atmosphere Inlets.

Atmosphere inlets shall not be located in such a way that atmosphere flow will directly impinge on temperature control or over temperature controlthermocouples. [86:13.5.11.10.8]

15.3.1.1.12 Special Atmosphere Safety Equipment.

Paragraphs 15.3.1.1.12.1 through 15.3.1.1.12.17 shall apply to the safety equipment and its application to the furnace special [hydrogen] atmospheresystem. [86:13.5.11.11]

15.3.1.1.12.1

All safety devices, with the exception of flow sensors, shall be one of the following:

(1) Listed for the service intended

(2) Approved where listed devices are not available

(3) Programmable controllers applied in accordance with Section 8.4 of NFPA 86

[86:13.5.11.11.1]

15.3.1.1.12.2

Electric relays and safety shutoff valves shall not be used as substitutes for electrical disconnects and manual shutoff valves. [86:13.5.11.11.2]

15.3.1.1.12.3

Regularly scheduled inspection, testing, and maintenance of all safety devices shall be performed. (See Section 15.3.1.1.8.) [86:13.5.11.11.3]

15.3.1.1.12.4

Safety devices shall be installed, used, and maintained in accordance with this standard and manufacturers’ instructions. [86:13.5.11.11.4]

15.3.1.1.12.5

Where a device is used with a flammable special [hydrogen] atmosphere gas and the device manufacturer’s instructions require conduit seals or a cabletype that will not permit transfer of gas, the required seals or cable type shall be installed. [86:13.5.11.11.5]

15.3.1.1.12.6

Safety devices shall be located or guarded to protect them from physical damage. [86:13.5.11.11.6]

* Regulator atmospheric vents shall be vented to an approved location. [86:13.5.11.10.3(B]

* Where a regulator vent is manifolded with other vents, the area of the vent manifold shall equal or exceed the sum of the individual vent line areas ofeach vent line served from its point of connection. [86:13.5.11.10.3(D)]

* Relief valves shall be provided downstream of any regulator where a regulator failure could expose downstream piping, components, or furnace topressures exceeding their maximum design pressure. [86:13.5.11.10.4(A)]

* Relief valve(s) or other means of controlling pressure shall be provided for each liquid special atmosphere piping system where there is a potential tooverpressurize the liquid special atmosphere piping. This specifically includes each section of liquid-filled special atmosphere piping that can beisolated by valves. [86:13.5.11.10.4(B)]

* Relief valves shall be piped to an approved location. [86:13.5.11.10.4(C)]


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15.3.1.1.12.7

Safety devices shall not be bypassed electrically or mechanically. [86:13.5.11.11.7]

(A)

The requirement in 15.3.1.1.12.7 shall not prohibit safety device testing and maintenance in accordance with Chapter 7. Where a system includes abuilt-in test mechanism that bypasses any safety device, it shall be interlocked to prevent operation of the system while the device is in test mode, unlesslisted for that purpose. [86:13.5.11.11.7(A)]

(B)

The requirement in 15.3.1.1.12.7 shall not prohibit a time delay applied to the action of pressure proving or flow proving, where the following conditionsexist:

(1) There is an operational need demonstrated for the time delay.

(2) The use of a time delay is approved.

(3) The time delay feature is not adjustable beyond 5 seconds.

(4) A single time delay does not serve more than one pressure-proving or flow-proving safety device.

(5) The time from an abnormal pressure or flow condition until the holding medium is removed from the safety shutoff valves does not exceed 5 seconds.

[86:13.5.11.11.7(B)]

15.3.1.1.12.8*

A manual emergency means shall be provided for the removal of the furnace special [hydrogen] atmosphere using the method, either purge-out orburn-out, that is the basis of the furnace design. [86:13.5.11.11.8]

15.3.1.1.12.9

The activation of any carrier gas or furnace pressure safety interlock required in 15.3.1.1.12 shall initiate the appropriate action to bring the furnace to asafe state. The action shall be manual or automatic in accordance with the furnace design and operating instructions. [86:13.5.11.11.9]

15.3.1.1.12.10 Removal of Flammable Special Atmospheres. [86:13.5.11.11.10]

(A)*

Removal of flammable special [hydrogen] atmospheres by burn-out, purge-out, or emergency purge-out shall be initiated under the following conditions:

(1) Normal furnace atmosphere burn-out initiated

(2) Normal furnace atmosphere purge-out initiated

(3) Low flow of carrier gas(es) that will not maintain a positive pressure in chambers below 1400°F (760°C) and positive pressure not restored by theautomatic transfer to another source of gas

(4) A furnace temperature below which any liquid carrier gas used will not reliably dissociate

(5) Automatic emergency inert gas purge initiated

(6) Manual operator emergency inert gas purge initiated

[86:13.5.11.11.10(A)]

(B)

When removal of flammable special [hydrogen] atmospheres is initiated in response to the conditions listed in 15.3.1.1.12.10(A)(3) through15.3.1.1.12.10(A)(6) , one of the following shall occur based upon chamber temperature:

(1) For chambers below 1400°F (760°C), one of the following actions shall occur, and the selected action shall be implemented as part of the furnacedesign:

(a) Automatically burned-out where burn-out is an acceptable option

(b) Purged-out by normal means where burn-out is not an acceptable option

(c) Automatically purged-out by emergency inert gas purge

(d) Manual burn-out or purge-out by manual emergency inert gas purge where furnace design allows the time needed for manual action

(2) For chambers at or above 1400°F (760°C), the chamber shall be manually or automatically burned-out or purged-out.

[86:13.5.11.11.10(B)]

15.3.1.1.12.11 Flammable Special Atmosphere Safety Shutoff Valves — General. [86:13.5.11.11.11]

(A)

One safety shutoff valve shall be provided in the supply line of each flammable special [hydrogen] atmosphere gas or liquid. [86:13.5.11.11.11(A)]

(B)*

Exothermic generated special [hydrogen] atmosphere gas supplies used for both purging and process shall not require safety shutoff valves.[86:13.5.11.11.11(B)]

(C)

Safety shutoff valve components shall be of materials selected for compatibility with the gas or liquid handled and for ambient conditions.[86:13.5.11.11.11(C)]

(D)

Means for testing all gas safety shutoff valves for valve seat leakage shall be installed. [86:13.5.11.11.11(D)]

(E)*

A test of seat leakage of gas safety shutoff valves shall be completed at least annually. [86:13.5.11.11.11(E)]

15.3.1.1.12.12 Flammable Special Atmosphere Safety Shutoff Valves. [86:13.5.11.11.12]


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(A)

For furnaces using burn-in procedures for introducing flammable special [hydrogen] atmosphere carrier gases, it shall be permissible to admit flammablespecial [hydrogen] atmosphere carrier gas when the following conditions exist:

(1) The furnace temperature exceeds 1400°F (760°C) at the point where the flammable special [hydrogen] atmosphere carrier gas is introduced.

(2) If the furnace is designed to operate with an automatic inert gas purge, the presence of the required inert gas pressure shall be verified manually orautomatically.

(3) Operator action opens the valve.

[86:13.5.11.11.12(A)]

(B)

For furnaces using purge-in procedures for introducing flammable special [hydrogen] atmosphere carrier gases, it shall be permissible to admit flammablespecial [hydrogen] atmosphere carrier gas when one following conditions exist:

(1) The inert gas purge is complete.

(2) If the furnace is designed to operate with an automatic inert gas purge, the presence of the required inert gas pressure shall be verified manually orautomatically.

(3) Operator action opens the valve.

[86:13.5.11.11.12(B)]

(C)

For furnaces using burn-in or purge-in procedures for introducing flammable special [hydrogen] atmosphere gases that are not carrier gases, the safetyshutoff valves for the noncarrier gases shall open only when the carrier gas flow has been established. [86:13.5.11.11.12(C)]

(D)*

Safety shutoff valves shall automatically close upon occurrence of the following conditions:

(1) Normal furnace atmosphere burn-out initiated

(2) Normal furnace atmosphere purge-out initiated


(4) A furnace temperature below which any liquid carrier gas used will not reliably dissociate

(5) Automatic emergency inert gas purge initiated


(7) Power failure

(8) Liquid carrier gas excess flow

[86:13.5.11.11.12(D)]

15.3.1.1.12.13 Emergency Inert Gas Purge. [86:13.5.11.11.13]

(A)

Where a furnace is designed for purge-out, the inert purge gas equipment pipe shall be controlled by a normally open purge control valve.[86:13.5.11.11.13(A)]

(B)

Where a furnace is equipped with an emergency inert gas purge, the emergency inert gas purge shall be initiated upon any of the following conditions:


(2) A furnace temperature below which sufficient dissociation of liquids intended for use as a carrier gas will not occur at levels required to maintainpositive furnace pressure


(4) Power failure

[86:13.5.11.11.13(B)]

15.3.1.1.12.14 Special Atmosphere Flow Interlocks. [86:13.5.11.11.14]

(A)

Minimum carrier gas flow(s) required by this standard shall be proved by either:

(1) A flow switch for each special atmosphere that is considered a carrier gas

(2) Furnace pressure switch(s)

[86:13.5.11.11.14]

(B)

If minimum carrier gas flow is not proven, the following shall be applied:

(1) Actions listed in 15.3.1.1.12.10(B) shall be initiated.

(2) Visual and audible alarms shall alert the operator of loss of minimum carrier gas flow.

[86:13.5.11.11.14(B)]


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(C)

Inert purge gas equipment piping shall be equipped with:

(1) A pressure switch that will audibly and visually alert the operator of a low purge pressure condition.

(2) A flow switch that will audibly and visually alert the operator of a low purge flow condition.

[86:13.5.11.11.14(C)]

15.3.1.1.12.15*

Furnace vestibules shall be equipped with means for explosion relief. [86:13.5.11.11.15]

15.3.1.1.12.16*

The flow of noncarrier special atmosphere gases that are nonflammable shall not be permitted until minimum carrier gas flow has been proven.[86:13.5.11.11.16]

15.3.1.1.12.17 Operating Precautions for Heating Cover–Type Furnaces.

The rate of separating a heating cover from or rejoining a heating cover to the inner cover shall not exceed a rate that causes rapid expansion orcontraction of the atmosphere gas inside the inner cover. [86:13.5.11.11.17]

15.3.1.1.13* Burner Management System Logic. [86:8.3]

15.3.1.1.13.1

Safety interlocks shall meet one or more of the following criteria:

(1) Be hardwired without relays in series and ahead of the controlled device

(2) Be connected to an input of a programmable controller logic system complying with 8.4 of NFPA 86

(3) Be connected to a relay that represents a single safety interlock that is configured to initiate safety shutdown in the event of power loss

(4) Be connected to a listed safety relay that represents one or more safety interlocks and initiates safety shutdown upon power loss

[86:8.3.1.3]

15.3.1.1.13.2*

Electrical power for safety control circuits shall be dc or single-phase ac, 250 volt maximum, one-side grounded, with all breaking contacts in theungrounded, fuse-protected, or circuit breaker–protected line. [86:8.3.1.4]

15.3.1.1.14

Programmable logic controller systems shall be in accordance with 8.4 of NFPA 86.

15.3.1.1.15* Inert Gas for Furnace Purge.

NFPA 86 identifies several specific situations where inert gas purge is required; NFPA 86 shall be referenced to identify the appropriate requirements.

15.3.1.1.15.1

Where inert purge gas is required by NFPA 86, the following shall apply:

(1) It shall be available at all times and be sufficient for five volume changes of all connected atmosphere furnaces.

(2) If the inert gas has a flammable gas component, it shall be analyzed on a continuous basis to verify that the oxygen content is less than 1 percent andthe combined combustible gas concentration remains less than 25 percent of the LFL.

[86:13.5.5.1(D)]

15.3.1.1.16

Where inert gases are used as safety purge media, the minimum volume stored shall be the amount required to purge all connected special [hydrogen]atmosphere furnaces with at least five furnace volume changes wherever the flammable atmospheres are being used. [86:13.5.5.1(F)]

15.3.1.1.17 Purge Gas Inventory.

15.3.1.1.17.1

Tanks containing purge media shall be provided with a low-level audible and visual alarm that meets the following criteria:

(1) The alarm is situated in the area normally occupied by furnace operators.

(2) The low-level alarm set point is established to provide time for an orderly shutdown of the affected furnace(s).

(3) The minimum contents of a tank containing a purge medium at the low-level alarm set point is sufficient to purge all connected atmosphere furnaceswith at least five volume changes.

[86:13.5.5.2]

15.3.1.2 Special Atmospheres in Class D Furnaces.

15.3.1.2.1 Safety Controls and Equipment.

The requirements of 15.3.1.2 shall apply to any vacuum chamber or vacuum furnace in which [hydrogen] gas is used at a pressure of 50 percent or moreof its lower flammable limit (LFL) in air. [86:14.5.3.1]

15.3.1.2.1.1

A minimum supply of inert purge gas equal to five times the total vacuum system volume shall be available during operation with flammable atmospheres.[86:14.5.3.1.1]

15.3.1.2.1.2

The purge gas supply shall be connected to the vacuum chamber through a normally open valve. [86:14.5.3.1.2]

(A)

A pressure sensor shall monitor the purge gas line pressure and shall stop the supply of flammable gas if the pressure becomes too low to allow purging inaccordance with 15.3.1.2.1.9.1. [86:14.5.3.1.2(A)]

(B)

Any manual inert purge gas shutoff valves shall be proved open through the use of a position monitoring switch and interlocked to prevent the introductionof flammable gas. [86:14.5.3.1.2(B)]


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15.3.1.2.1.3 Flammable Gas Supply. [86:14.5.3.1.3]

(A)

The flammable gas supply shall be connected to the vacuum chamber through a normally closed automatic safety shutoff valve. [86:14.5.3.1.3(A)]

(B)

Vacuum furnaces that rely on a partial vacuum to hold the door closed shall have the flammable gas supply connected to the vacuum chamber through twonormally closed automatic safety shutoff valves. [86:14.5.3.1.3(B)]

(C)

A manual shutoff valve shall be provided in all flammable atmosphere supply pipe(s). [86:14.5.3.1.3(C)]

15.3.1.2.1.4

The flammable gas supply system shall be interlocked with the vacuum system to prevent the introduction of any flammable atmosphere until the furnace

has been evacuated to a level of 1 × 10-1 torr (13.3 Pa) or less. [86:14.5.3.1.4]

15.3.1.2.1.5

High and low pressure switches shall be installed on the flammable gas line and shall be interlocked to shut off the supply of gas when its pressuredeviates from the design operating range. [86:14.5.3.1.5]

15.3.1.2.1.6*

In the case of a multiple chamber-type or continuous-type vacuum furnace, the following criteria shall apply:

(1) Each chamber shall be regarded as a separate system.

(2) Interlocks shall be provided that prevent the valves from opening between adjacent interconnecting chambers once a flammable atmosphere hasbeen introduced into any of them.

[86:14.5.3.1.6]

15.3.1.2.1.7

The vacuum pumping system shall be interlocked with the supply gas system so that mechanical pumps continue to operate while flammable gas is in thevacuum chamber, to prevent the backflow of air through nonoperating pumps. [86:14.5.3.1.7]

15.3.1.2.1.8

The following shall be piped to a source of inert gas:

(1) Mechanical pump gas ballast valves

(2) Vacuum air release valves on roughing or forelines

[86:14.5.3.1.8]

15.3.1.2.1.9

Manual air release valves shall not be permitted. [86:14.5.3.1.9]

15.3.1.2.1.10

Vacuum furnaces that rely on a partial vacuum to hold the door closed shall incorporate a pressure switch, independent of the chamber pressure controldevice, to terminate flammable gas addition before the backfill pressure rises to a point where door clamping is lost. [86:14.5.3.1.10]

15.3.1.2.1.11

Vacuum furnaces that are backfilled with flammable gases to pressures greater than that required to hold the door closed shall incorporate clamps andseals to ensure the door is tightly and positively sealed. [86:14.5.3.1.11]

15.3.1.2.1.12*

Sight glasses, where provided, shall be valved off before operation with flammable gases, except for sight glasses used solely for pyrometers.[86:14.5.3.1.12]

15.3.1.2.2 Flammable Gases. [86:14.5.3.2]

15.3.1.2.2.1

During processing, flammable gases shall be exhausted from vacuum furnaces by pumping them through the vacuum pumps or by venting in continuousflow to the atmosphere. [86:14.5.3.2.1]

15.3.1.2.2.2

If the flammable gas is exhausted through a vacuum pump, the system shall be designed to prevent air backflow if the pump stops. [86:14.5.3.2.2]

15.3.1.2.2.3

Venting of the vacuum pump shall be in accordance with 14.2.7 of NFPA 86, and one of the following actions shall be taken during flammable gasoperation:

(1) The pump discharge shall be diluted with inert gas to lower the combustible level of the mixture below the LFL.

(2) The pump discharge shall be passed through a burner.

[86:14.5.3.2.3]

15.3.1.2.2.4

If the flammable gas is vented to the atmosphere directly without passing through the vacuum pumps, the vent line shall be provided with a means ofpreventing air from entering the furnace chamber. [86:14.5.3.2.4]

15.3.1.2.2.5

If the flammable gas is vented to the atmosphere through a burner, the vent line shall be provided with a means of preventing air from entering the furnacechamber, and the following criteria also shall apply:

(1) The existence of the burner ignition source shall be monitored independently.

(2) Interlocks shall be provided to shut off the flammable gas supply and initiate inert gas purge if the flame is not sensed.

[86:14.5.3.2.5]


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15.3.1.2.2.6

Where flammable gas is used to maintain chamber pressure above atmospheric pressure, the following criteria shall be met:

(1) A pressure switch shall be interlocked to close the flammable gas supply if the chamber pressure exceeds the maximum operating pressure.

(2) The pressure switch shall be independent of the chamber pressure control device.

[86:14.5.3.2.6]

15.3.1.2.2.7

Where flammable gas is used to maintain chamber pressure above atmospheric pressure, the following criteria shall be met:

(1) A pressure switch shall be interlocked to close the flammable gas supply and initiate purge if the chamber pressure drops below the minimumoperating pressure.

(2) The pressure switch shall be independent of the chamber pressure control device.

[86:14.5.3.2.7]

15.3.1.2.2.8

Where flammable gas is exhausted through a vent (not through the pump), the vent valve shall not open until a pressure above atmosphere is attained inthe chamber. [86:14.5.3.2.8]

15.3.1.2.3 Removal of Flammable Gas — Purging. [86:14.5.3.3]

15.3.1.2.3.1

When purge is initiated, the flammable gas valve(s) shall be closed. [86:14.5.3.3 (A)]

15.3.1.2.3.2

Purging shall be complete when any of the following criteria is satisfied: [86:14.5.3.3 (B)]

(1) Two consecutive analyses of the vent gas from the furnace indicate that less than 50 percent of the LFL has been reached. [86:14.5.3.3(B)(1)]

(2) Five furnace volume changes with inert gas have occurred. [86: 14.5.3.3(B)(2)]

(3) The furnace is pumped down to a minimum vacuum level of 1 × 10-1 torr (13.3 Pa) prior to inert gas backfill. [86:14.5.3.3(B)(3)]

15.3.1.2.4* Emergency Shutdown Procedure.

In the event of an electrical power failure or flammable gas failure, the system shall be purged in accordance with 15.3.1.2.3. [86:14.5.3.4]

15.3.2* Hydrogen Cooled Generators.

15.3.2.1 General.

15.3.2.1.1

Subsection 15.3.2 shall apply to electric power-generating equipment that employs a hydrogen atmosphere to provide cooling of the equipment or power-generation efficiency gains or both.

15.3.2.1.1.1

The storage and delivery piping systems and equipment for hydrogen-cooled generators shall comply with the applicable requirements of Chapters 1through 4 and 6 through 8 and the modifications identified herein.

15.3.2.1.1.2

If the hydrogen supply is an active gas-generation device, such as an electrolyzer or a reformer, the applicable provisions of Chapter 13 shall apply.

15.3.2.1.2 Monitoring of Hydrogen Atmosphere.

15.3.2.1.2.1

The internal atmosphere of the generator shall be monitored to ensure maintenance of hydrogen purity at 85 percent or better.

15.3.2.1.2.2

Warnings of low purity shall be provided to the operator(s).

15.3.2.1.3 Ignition Sources.

15.3.2.1.3.1*

The area classification around hydrogen-cooled generators shall, as a minimum, be in accordance with ANSI/IEEE C2, National Electrical Safety Code.

15.3.2.1.3.2

Installations in which the generator is coupled to the exhaust end of a gas turbine, or in which the high-pressure section of a steam turbine results in thegenerator being in the proximity of hot surfaces that might exceed 1000°F (538°C), shall require risk mitigations for potentially hazardous areas associatedwith the generator intersecting such hot surfaces.

15.3.2.1.3.3

As a function of necessary design, generators might contain electrical ignition sources in close proximity (i.e., field excitation brushes, shaft groundingbrushes, and various high-current electrical devices necessary for control of the generator output.

15.3.2.1.3.4

The presence of potential ignition sources shall be considered when providing risk mitigation.

15.3.2.1.4 Seal Oil Systems.

15.3.2.1.4.1

Where seal oil systems are used, the oil pressure shall be monitored to detect system failure.

(A)

Where automatic shutdown capability exists, system failure shall automatically shut the unit down.

(B)

If there is no automatic shutdown capability, an operator alarm shall be provided to enable timely operator action to shut the unit down.


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15.3.2.1.4.2

The seal oil system shall include a secondary system capable of providing full seal oil pressure for the time required to reduce the speed to themanufacturer’s recommended RPM to purge the generator of hydrogen.

15.3.2.1.4.3

Where an automatic purge capability is available, loss of seal oil pressure shall initiate the automatic purge of the generator hydrogen once the unit RPMhas been reduced to the manufacturer’s recommended purge speed.

15.3.2.1.4.4

Warnings of loss of seal oil pressure shall be provided to the operator(s).

15.3.2.2 Indoor Installations.

15.3.2.2.1*

Buildings that enclose hydrogen-cooled generator installations shall be ventilated to avoid flammable gas buildup from potential system leaks.

15.3.2.2.2

The building ceiling shall avoid features that could trap hydrogen gas, such as solid beams that form a tight fit with the roof deck.

15.3.2.2.3

The building designer shall consider the use of redundant fans and hydrogen detection systems in the design of the ventilation system.

15.3.2.2.4*

All hydrogen system vents shall be routed to an appropriate area outside the building and meet the requirements of Chapters 5 through 8, as applicable.

15.3.2.3 Outdoor Installations.

15.3.2.3.1

The potentially hazardous area surrounding a hydrogen-cooled generator and associated equipment shall not intersect with heating, ventilating, andair-conditioning (HVAC) air intakes and windows, doors, and other openings into occupied spaces (e.g., control rooms and break rooms).

15.3.2.3.2*

All hydrogen system vents shall be routed to an appropriate point above other equipment and buildings and meet the requirements of Chapters 5 through8 as applicable.

15.4 Storage.

15.4.1 Requirements for Hydrogen Storage Systems Serving Furnace Installations.

15.4.1.1* General.

The storage of GH2 or LH2 serving furnace installations shall be in accordance with Chapters 6 through 8, as applicable.



15.4.2 Requirements for Hydrogen Storage Systems Serving Hydrogen-Cooled Generators.

15.4.2.1 General.

The storage of GH2 or LH2 serving hydrogen-cooled generators shall be in accordance with Chapters 6 through 8, as applicable.





160308_NFPA_2_Chp_15.docx Alternative comments


In my opinion, this chapter should be limited to add/delete from NFPA 86. NFPA 86 is not a code, it is a standard. It is also the bible for furnace manufacturers since 1931. They are not going to go to NFPA 2. We should send the reader to NFPA 86.

Since there are currently no add/deletes, the scope should send you to NFPA 86 and the balce of the chapter should be deleted.




Street Address:

City:

State:

Zip:



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WPCSOL, LLC

To: K. Hall & J. Keller 2016 March 08

From: W. Collins Subject: Input to FCHEA on proposed changes to NFPA 2 Chapter 15 CC: R. Boyd W. James E. Steele R. Burgess C. Rivkin S. Goyette G. Scheffler Objective: The objective of this memorandum is to suggest modifications to chapter 15 of NFPA 2-2016. Discussion: Comments are in Appendix A. In my opinion, this chapter should be limited to add/delete from NFPA 86. NFPA 86 is not a code, it is a standard. We extract from a code, reference a standard. In trying to extract, we lose context. We should state something like “The rule set for furnaces set forth in NFPA 86 shall be followed with the following modifications”. Then

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Appendix A

Comments on chapter 15

Chapter 15 Special Atmosphere Applications

Why doesn’t this just reference NFPA 86 which is a standard, not a code, instead or extracted sections?

15.3 Use. 15.3.1 Furnaces. 15.3.1.1.1.1 Subsection 15.3.1 shall apply to special atmospheres containing hydrogen used in Class C or Class D furnaces.

What are class C and D furnaces? 15.3.1.1.4 Flow Control of Special [Hydrogen] Atmospheres. [86:13.5.7] 15.3.1.1.4.3* Where the atmosphere is flammable, its flow rate shall be sufficient to provide stable burn-off flames or dilution mixture at vent ports. [86:13.5.7.3]

15.3.1.1.3 allows both. 15.3.1.1.5* Special Processing Hydrogen Atmosphere Gas Mixing Systems.

(3) *Piping and components shall be in accordance with ASME B31.1, appropriate volume Code for Pressure Piping.

Don’t limit to section 1 of B31.

15.3.1.1.6 Synthetic Atmosphere Flow Control. 15.3.1.1.6.2 A safety interlock shall be provided for preventing the initial introduction of [any] flammable fluid into a furnace before the furnace temperature has risen to 1400°F (760°C). [86:13.5.8.2]

Why 760oC (1400oF) which is 150% above the AIT? Typically it is 120%, which for hydrogen is 600oC (1112oF), call it 1100oF.

1400oF is ~117% of the AIT for ammonia. Is this a forming gas requirement? I suspect that it is.

15.3.1.1.6.6 * Safety relief valves to prevent over pressurizing of glass tube flowmeters and all other system components shall be in accordance with ASME B31.1, appropriate volume Code for Pressure Piping. [86:13.5.8.8]

Don’t limit to section 1 of B31.

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15.3.1.1.11 Design Requirements for the Introduction, Use, and Removal of Flammable and Indeterminate Special Atmospheres from Furnaces. [86:13.5.11.1] 15.3.1.1.11.1 General.

(F)* Process control air or burnout air shall be supplied from an air blower. [86:13.5.11.1(F)]

Process control air or burnout air shall be supplied from a pressurized source (i.e. natural draft is inadequate).

15.3.1.1.11.6 Purge-in Requirements.

(B)Purge-in shall reduce the oxygen content of the furnace to less than 1 percent by displacement with

an inert gas or before introduction of the flammable special [hydrogen] atmosphere gas. [86:13.5.11.6.2]

Why 1%? The UFL of H2/Air is 75% or 5% oxygen and 5% at room temperature is non-flammable?

15.3.1.1.11.7 Burn-in Requirements.

(C)* To begin the burn-in process, the flammable special [hydrogen] atmosphere gas shall be introduced at a location in the furnace that is at or above 1400°F (760°C). [86:13.5.11.7.3]

See 15.3.1.1.6.2

(D)* Where a stable flame front propagating through a chamber under 1400°F (760°C) cannot be maintained, the burn-in process shall not be used. [86:13.5.11.7.4]

See 15.3.1.1.6.2

(E)* For zones under 1400°F (760°C), stable flames of burning gas shall be maintained in the zones as the special [hydrogen] atmosphere gas is burned-in. [86:13.5.11.7.5]

See 15.3.1.1.6.2

15.3.1.1.11.9 Burn-Out Requirements.

(C)* To initiate the burn-out process, one of the following conditions shall be met:

(1)Air is introduced into the furnace at a point that is at or above 1400°F (760°C).

See 15.3.1.1.6.2 (2)Where air is introduced into a furnace at a point below 1400°F (760°C), the following shall apply:

See 15.3.1.1.6.2

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(F)* During burn-out, recirculating fans shall be turned off in furnace zones under 1400°F (760°C) and

in zones at or above 1400°F (760°C) that can cause turbulence in zones under 1400°F (760°C). [86:13.5.11.9.6] See 15.3.1.1.6.2

15.3.1.1.11.10* Special Atmosphere Equipment Piping System. [86:13.5.11.10]

(G)Pressure Gauges. Pressure gauges shall be provided at points in the special [hydrogen] atmosphere equipment piping where the operator must be provided visual pressure information to verify the furnace is being maintained within safe operating limits. These points shall be determined as part of the furnace design. [86:13.5.11.10.7]

Why are pressure transducers not allowed?

15.3.1.1.12 Special Atmosphere Safety Equipment. 15.3.1.1.12.10 Removal of Flammable Special Atmospheres. [86:13.5.11.11.10]

(B)When removal of flammable special [hydrogen] atmospheres is initiated in response to the

conditions listed in 15.3.1.1.12.10(A)(3) through 15.3.1.1.12.10(A)(6), one of the following shall occur based upon chamber temperature:

(1)For chambers below 1400°F (760°C), one of the following actions shall occur, and the selected

action shall be implemented as part of the furnace design:

See 15.3.1.1.6.2

(2)For chambers at or above 1400°F (760°C), the chamber shall be manually or automatically burned-out or purged-out. [86:13.5.11.11.10(B)]

See 15.3.1.1.6.2

15.3.1.1.12.12 Flammable Special Atmosphere Safety Shutoff Valves. [86:13.5.11.11.12]

(A) For:

(1) The furnace temperature exceeds 1400°F (760°C) at the point where the flammable special [hydrogen] atmosphere carrier gas is introduced.

See 15.3.1.1.6.2

(D)* Safety:

(3)Low flow of carrier gas(es) that will not maintain a positive pressure in chambers below 1400°F (760°C) and positive pressure not restored by the automatic transfer to another source of gas

See 15.3.1.1.6.2

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15.3.1.1.15* Inert Gas for Furnace Purge. 15.3.1.1.15.1

(2)If the inert gas has a flammable gas component, it shall be analyzed on a continuous basis to verify that the oxygen content is less than 1 percent and the combined combustible gas concentration remains less than 25 percent of the LFL. [86:13.5.5.1(D)] See 15.3.1.1.11.6 (B)

15.3.1.2 Special Atmospheres in Class D Furnaces.

See 15.3.1.1.1.1

15.3.1.2.1 Safety Controls and Equipment. The requirements of 15.3.1.2 shall apply to any vacuum chamber or vacuum furnace in which [hydrogen] gas is used at a pressure of 50 percent or more of its lower flammable limit (LFL) in air. [86:14.5.3.1]

What? … at a pressure of 50 percent or more of the LFL?

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Chapter 16 Laboratory Operations

16.1 Scope.

The requirements of this chapter shall apply to the storage, use, and handling of GH2 and LH2 in laboratories, laboratory buildings, laboratory units, or

laboratory work areas as defined by Chapter 3.

16.1.1 Application.

16.1.1.1

The requirements of this chapter shall apply to the storage, use, handling, or dispensing of GH 2 in laboratory buildings, laboratory units, and laboratory

work areas, whether located above or below grade, when the amount of GH 2 exceeds 75 scf (2.2 standard m 3 ) or the amount of LH 2 exceeds 1 gal

(3.8 L).

16.1.1.2

The storage, use, and handling of GH 2 in any quantity shall also comply with the requirements of Chapters 1 through 4 and the requirements of Chapters

5 through 8, as applicable.

16.1.1.3


16.1.1.4

The use-specific requirements of this chapter for hydrogen in laboratory operations shall apply.

16.1.1.5


16.1.2

This chapter shall not apply to the following:

(1) Laboratory units that contain less than 75 scf (2.2 standard m 3 ) of GH 2 or 1 gal (3.8 L) of LH 2

(2)

(3) Laboratories that are primarily manufacturing plants

(4) Incidental testing facilities

16.2 General.

16.2.1 Means of Access to an Exit.

16.2.1.1 *

A second means of access to an exit shall be provided from a laboratory work area if any of the following situations exist: [ 45: 5.4.1]

(1) A laboratory work area contains an explosion hazard located so that an incident would block escape from or access to the laboratory work area.[ 45: 5.4.1(1)]

(2) A hood in a laboratory work area is located adjacent to the primary means of exit access. [ 45: 5.4.1(4)]

(3) A compressed gas cylinder larger than lecture bottle size [approximately 2 in. × 13 in. (5 cm × 33 cm)] is located such that it could prevent safeegress in the event of accidental release of cylinder contents. [ 45: 5.4.1(5)]

(4) A cryogenic container is located such that it could prevent safe egress in the event of accidental release of container contents. [ 45: 5.4.1(6)]

16.2.1.2

Emergency lighting facilities shall be provided for any laboratory work area requiring a second means of access to an exit, in accordance with 16.2.1.1 .[ 45: 5.4.4]

16.2.1.3

Emergency lighting in laboratory work areas and exits shall be installed in accordance with Section 7.9, Emergency Lighting, of NFPA 101 . [ 45: 5.4.5]

16.2.2 Electrical Installation.

All electrical installations, including wiring and appurtenances, apparatus, lighting, signal systems, alarm systems, remote control systems, or parts thereof,shall comply with NFPA 70 . [ 45: 5.6]

16.2.2.1 *

Laboratory work areas, laboratory units, and chemical fume hood interiors shall be considered as unclassified electrically with respect to Article 500 ofNFPA 70 , unless operations are determined to cause a hazardous atmosphere. [ 45: 5.6.2]

16.2.3 Fire Protection.

16.2.3.1 Automatic Fire Extinguishing Systems.

16.2.3.1.1 Automatic Sprinkler Systems.

16.2.3.1.1.1

A fire protection system shall be provided for laboratories in accordance with Chapter 6.

16.2.3.1.1.2 *

Fire sprinklers in laboratory units shall be the quick-response (QR) sprinkler type installed in accordance with NFPA 13. [ 45: 6.1.1.2]

* Laboratories that are pilot plants


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16.2.3.1.1.3

Automatic sprinkler systems shall be regularly inspected, tested, and maintained in accordance with NFPA 25. [ 45: 6.1.1.3]

16.2.3.2 Fire Alarm Systems.

16.2.3.2.1

A fire alarm system shall be provided for laboratories in accordance with Chapter 6.

16.2.3.2.2

The fire alarm system, where provided, shall be designed so that all personnel endangered by the fire condition or a contingent condition shall be alerted.[ 45: 6.4.3]

16.2.3.2.3

The fire alarm system shall alert local emergency responders or the public fire department. [ 45: 6.4.4]

16.2.3.3 Standpipe and Hose Systems.

16.2.3.3.1 *

In all laboratory buildings that are two or more stories above or below the grade level (level of exit discharge), Class I wet pipe standpipesystems shall beinstalled in accordance with NFPA 14. [ 45: 6.2.1]

16.2.3.3.2 *

Standpipe systems shall be regularly inspected, tested, and maintained in accordance with NFPA 25. [ 45: 6.2 2]

16.2.3.4 Portable Fire Extinguishers.

16.2.3.4.1

Portable fire extinguishers shall be installed, located, and maintained in accordance with NFPA 10. [ 45: 6.3.1]

16.2.4 Explosion Hazard Protection.

16.2.4.1

A laboratory work area shall be considered to contain an explosion hazard if an explosion involving hydrogen could result in significant damage to a facilityor serious injuries to personnel within that laboratory work area.

16.2.5 Fire Prevention.

16.2.5.1 Fire Prevention Procedures.

16.2.5.1.1

Fire prevention procedures shall be established for all new and existing laboratories. [ 45: 6.5.1.1]

16.2.5.1.2

Fire prevention procedures shall include, but not be limited to, the following:

(1) Handling and storage of [GH 2 and LH 2 ]

(2) Open flame and spark-producing equipment work permit system

(3) Arrangements and use of portable electric cords

(4) Smoking area controls

[ 45: 6.5.1.2]

16.2.5.2 * Maintenance Procedures.

Maintenance procedures shall be established for all new and established laboratories. [ 45: 6.5.2]

16.2.5.3 * Emergency Plans.

16.2.5.3.1

Plans for laboratory emergencies shall be established for all new and existing laboratories. The emergency action plan shall include the followingprocedures in the event of a chemical emergency, fire, or explosion:

(1) Procedures for sounding the alarm

(2) Procedures for notifying and coordinating with the fire department, governmental agencies, or other emergency responders or contacts, as required

(3) Procedures for evacuating and accounting for personnel, as applicable

(4) Procedures for establishing requirements for rescue and medical duties for those requiring or performing these duties

(5)

(6) Procedures for shutting down and isolating equipment under emergency conditions to include the assignment of personnel responsible formaintaining critical functions or for shutdown of process operations

(7) Appointment and training of personnel to carry out assigned duties, including steps to be taken at the time of initial assignment, as responsibilities orresponse actions change, and at the time anticipated duties change

(8) Alternative measures for occupant safety, when applicable

(9) Aisles designated as necessary for movement of personnel and emergency response

(10) Maintenance of fire protection equipment

(11) Safe procedures for startup to be taken following the abatement of an emergency

[ 400: 7.2.3.2]

16.2.5.3.2 *

Procedures for extinguishing clothing fires shall be established for all new and existing laboratories. [ 45: 6.5.3.2]

* Procedures and schedules for conducting drills


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16.2.5.3.3

All laboratory users, including, but not limited to, instructors and students, shall be trained prior to laboratory use and at least annually thereafter on theemergency plan. [ 45: 6.5.3.3]

16.3 Use.

16.3.1 General.

16.3.1.1 Instructional Laboratories.

Experiments and tests conducted in educational and instructional laboratory units shall be under the direct supervision of an instructor.

16.3.1.2 Cylinders in Use.

16.3.1.2.1

Cylinders, when in use, shall be connected to gas delivery systems designed by a qualified person. [ 45: 10.1.6.1]

16.3.1.2.2

Cylinders shall be attached to an instrument for use by means of a regulator. [ 45: 10.1.6.2]

16.3.1.2.3

A compressed gas cylinder shall be considered to be “in use” if it is in compliance with one of the following:

(1) Connected through a regulator to deliver gas to a laboratory operation

(2) Connected to a manifold being used to deliver gas to a laboratory operation

(3) A single cylinder secured alongside the cylinder described in 16.3.1.2.3 (1) as the reserve cylinder for the cylinder described in 16.3.1.2.3 (1).

[ 45: 10.1.6.3]

16.3.1.2.4

Cylinders not “in use” shall not be stored in the laboratory unit. [ 45: 10.1.6.4]

16.3.2 Indoor Use.

16.3.2.1 Laboratory Ventilating Systems and Hood Requirements.

16.3.2.1.1 * General.

16.3.2.1.1.1

This chapter shall apply to laboratory exhaust systems, including chemical fume hoods, local ventilated enclosures, fume arms, special local exhaustdevices, and other systems for exhausting air from laboratory work areas in which [GH 2 or LH 2 ] are released. [ 45: 7.1.1]

16.3.2.1.1.2

This chapter shall apply to laboratory air supply systems and shall provide requirements for identification, inspection, and maintenance of laboratoryventilation systems and hoods. [ 45: 7.1.2]

16.3.2.1.2 Basic Requirements.

16.3.2.1.2.1 *

Laboratory ventilation systems shall be designed to ensure that fire hazards and risks are minimized. [ 45: 7.2.1]

16.3.2.1.2.2 *

Laboratory units and laboratory hoods in which [GH 2 or LH 2 ] are present shall be continuously ventilated under normal operating conditions. [ 45: 7.2.2]

16.3.2.1.2.3 *

Chemical fume hoods shall not be relied upon to provide explosion (blast) protection unless specifically designed to do so. (See also G.6.4 and G.6.5for further information on explosion-resistant hoods and shields.) [ 45: 7.2.3]

16.3.2.1.2.4

Exhaust and supply systems shall be designed to prevent a pressure differential that would impede egress or ingress when either system fails or during afire or emergency scenario. This design includes reduced operational modes or shutdown of either the supply or exhaust ventilation systems. [ 45: 7.2.5]

16.3.2.1.2.5

The release of [GH 2 ] into the laboratory shall be controlled by enclosure(s) or captured to prevent any flammable concentrations of vapors from reaching

any source of ignition. [ 45: 7.2.6]

16.3.2.1.3 Supply Systems.

16.3.2.1.3.1

Laboratory ventilation systems shall be designed to ensure that [GH 2 ] originating from the laboratory shall not be recirculated. [ 45: 7.3.1]

16.3.2.1.3.2 *

The location and configuration of fresh air intakes shall be chosen so as to avoid drawing in [GH 2 ] or products of combustion coming either from the

laboratory building itself or from other structures and devices. [ 45: 7.3.2]


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16.3.2.1.3.3

The air pressure in the laboratory work areas shall be negative with respect to corridors and non-laboratory areas of the laboratory unit except in thefollowing instances:

(1) Where operations such as those requiring clean rooms preclude a negative pressure relative to surrounding areas, alternate means shall beprovided to prevent escape of the atmosphere in the laboratory work area or unit to the surrounding spaces.

(2) The desired static pressure level with respect to corridors and non-laboratory areas shall be permitted to undergo momentary variations as theventilation system components respond to door openings, changes in chemical fume hood sash positions, and other activities that can for a shortterm affect the static pressure level and its negative relationship.

(3) Laboratory work areas located within a designated electrically classified hazardous area with a positive air pressure system as described inNFPA 496, Chapter 7, Pressurized Control Rooms, shall be permitted to be positive with respect to adjacent corridors.

[ 45: 7.3.3]

16.3.2.1.3.4 *

The location of air supply diffusion devices shall be chosen so as to avoid air currents that would adversely affect the performance of chemical fume hoods,exhaust systems, and fire detection or extinguishing systems. (See 16.2.3.1 , 16.2.3.2 , and 16.3.2.1.8.1 .) [ 45: 7.3.4]

16.3.2.1.4 Exhaust Air Discharge.

16.3.2.1.4.1 *

Air exhausted from chemical fume hoods and other special local exhaust systems shall not be recirculated. (See also 16.3.2.1.3.1 .) [ 45: 7.4.1]

16.3.2.1.4.2 * Energy Conservation Devices.

(A)

If energy conservation devices are used, they shall be designed in accordance with 16.3.2.1.3.1 through 16.3.2.1.3.3 . [ 45: 7.4.2.1]

(B)

Energy conservation devices shall only be used in a laboratory ventilation system when evaluated and approved by a qualified person. These systemsmust meet, or exceed, the criteria established by Section 5.4.7 and Section 5.4.7.1 of ANSI/AIHA Z9.5, 2012, Laboratory Ventilation . Systems thatrecirculate within their respective laboratory area, such as fan coil units for sensible heat loads, are exempt from these requirements. [ 45: 7.4.2.2]

(C)

Energy conservation devices shall be designed and installed in a manner that safely facilitates anticipated service and maintenance requirements and doesnot adversely impact the proper operation of the exhaust system. [ 45: 7.4.2.3]

16.3.2.1.4.3

Air exhausted from laboratory work areas shall not pass unducted through other areas. [ 45: 7.4.3]

16.3.2.1.4.4 *

Air from laboratory units and laboratory work areas in which [GH 2 ] is present shall be continuously discharged through duct systems maintained at a

negative pressure relative to the pressure of normally occupied areas of the building. [ 45: 7.4.4]

16.3.2.1.4.5

Positive pressure portions of the lab hood exhaust systems (e.g., fans, coils, flexible connections, and ductwork) located within the laboratory building shallbe sealed airtight or located in a continuously mechanically ventilated room. [ 45: 7.4.5]

16.3.2.1.4.6

Chemical fume hood face velocities and exhaust volumes shall be sufficient to contain [GH 2 ] generated within the hood and exhaust them outside of the

laboratory building. [ 45: 7.4.6]

16.3.2.1.4.7 *

The hood shall provide containment of the possible hazards and protection for personnel at all times when [GH 2 is] present in the hood. [ 45: 7.4.7]

16.3.2.1.4.8

Special local exhaust systems, such as snorkels or “elephant trunks,” shall have sufficient capture velocities to entrain the [GH 2 ] being released.

[ 45: 7.4.8]

16.3.2.1.4.9 *

Canopy hoods, laminar flow cabinets, and ductless enclosures shall not be used in lieu of chemical fume hoods. [ 45: 7.4.9]

16.3.2.1.4.10

Laminar flow cabinets shall not be used in lieu of chemical fume hoods. [ 45: 7.4.11]

16.3.2.1.4.11 *

Air exhausted from chemical fume hoods and special exhaust systems shall be discharged above the roof at a location, height, and velocity sufficient toprevent re-entry of chemicals and to prevent exposures to personnel. [ 45: 7.4.12]

16.3.2.1.5 Duct Construction for Hoods and Local Exhaust Systems.

16.3.2.1.5.1

Ducts from chemical fume hoods and from local exhaust systems shall be constructed entirely of noncombustible materials except in the following cases:

(1) Flexible ducts of combustible construction shall be permitted to be used for special local exhaust systems within a laboratory work area. (See16.3.2.1.5.2 .)

(2) Combustible ducts shall be permitted to be used if enclosed in a shaft of noncombustible or limited-combustible construction where they passthrough non-laboratory areas or through laboratory units other than the one they serve. (See 16.3.2.1.5.2 .)

(3) Combustible ducts shall be permitted to be used if all areas through which they pass are protected with an approved automatic fire extinguishingsystem, as described in 16.2.3 . (See 16.3.2.1.5.2 .) [ 45: 7.5.1]


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16.3.2.1.5.2

Combustible ducts or duct linings shall have a flame spread index of 25 or less when tested in accordance with ASTM E84 Standard Test Method forSurface Burning Characteristics of Building Materials , or ANSI/UL 723, Standard for Test for Surface Burning Characteristics of Building Materials . Testspecimens shall be of the minimum thickness used in the construction of the duct or duct lining. [ 45: 7.5.2]

16.3.2.1.5.3

Ducts shall be of adequate strength and rigidity to meet the conditions of service and installation requirements and shall be protected against mechanicaldamage. [ 45: 7.5.5]

16.3.2.1.5.4

Materials used for vibration isolation connectors shall comply with 16.3.2.1.5.2 . [ 45: 7.5.6]

16.3.2.1.5.5

Controls and dampers, where required for balancing or control of the exhaust system, shall be of a type that, in event of failure, will fail open to ensurecontinuous draft. (See 16.3.2.1.9.3 through 16.3.2.1.9.5 .) [ 45: 7.5.8]

16.3.2.1.5.6

Hand holes, where installed for damper, sprinkler, or fusible link inspection or resetting and for residue clean-out purposes, shall be equipped with tight-fitting covers provided with substantial fasteners. [ 45: 7.5.9]

16.3.2.1.5.7 Manifolding of Chemical Fume Hood and Ducts.

(A)

Exhaust ducts from each laboratory unit shall be separately ducted to a point outside the building, to a mechanical room, or to a shaft. [ 45: 7.5.10.1]

(B)

Connection to a common chemical fume hood exhaust duct system shall be permitted to occur within a building only in any of the following locations:

(1) A mechanical room, not connected to a shaft, shall be protected in accordance with Table 5.1.1 of NFPA 45.

(2) A shaft or a mechanical room connected to a shaft, shall be protected in accordance with the chapter for protection of vertical openings of NFPA101

(3) A point outside the building

[ 45: 7.5.10.2]

(C)

Exhaust ducts from chemical fume hoods and other exhaust systems within the same laboratory unit shall be permitted to be combined within thatlaboratory unit. (See 16.3.2.1.4.1 .) [ 45: 7.5.10.3]

16.3.2.1.6 Exhausters (Fans), Controls, Velocities, and Discharge.

16.3.2.1.6.1

Fans shall be selected to meet requirements for fire, explosion, and corrosion. [ 45: 7.7.1]

16.3.2.1.6.2

Fans conveying both corrosive and flammable or combustible materials shall be permitted to be lined with or constructed of corrosion-resistant materialshaving a flame spread index of 25 or less when tested in accordance with ASTM E84, Standard Test Method for Surface Burning Characteristics ofBuilding Materials, or ANSI/UL 723, Standard for Test for Surface Burning Characteristics of Building Materials. [ 45: 7.7.2]

16.3.2.1.6.3

Fans shall be located and arranged so as to afford ready access for repairs, cleaning, inspection, and maintenance. [ 45: 7.7.3]

16.3.2.1.6.4 *

Where [GH 2 is] passed through the fans, the rotating element shall be of nonferrous or spark-resistant construction; alternatively, the casing shall be

constructed of or lined with such material. [ 45: 7.7.4]

(A)

Nonferrous or spark-resistant materials shall have a flame spread index of 25 or less when tested in accordance with ASTM E84, Standard Test Methodfor Surface Burning Characteristics of Building Materials, or ANSI/UL 723, Standard for Test for Surface Burning Characteristics of Building Materials.[ 45: 7.7.4.2]

16.3.2.1.6.5

Motors and their controls shall be located outside the location where [GH 2 is] generated or conveyed, unless specifically approved for that location and

use. [ 45: 7.7.5]

16.3.2.1.6.6 *

Fans shall be marked with an arrow or other means to indicate direction of rotation and with the location of chemical fume hoods and exhaust systemsserved. [ 45: 7.7.6]

16.3.2.1.7 Chemical Fume Hood Construction.

(See also 16.3.2.1.2.2 ) [ 45: 7.8]

16.3.2.1.7.1 Chemical Fume Hood Interiors.

(A) *

Materials of construction used for the interiors of new chemical fume hoods or for the modification of the interiors of existing chemical fume hoods shallhave a flame spread index of 25 or less when tested in accordance with ASTM E84, Standard Test Method for Surface Burning Characteristics of BuildingMaterials, or ANSI/UL 723, Standard for Test for Surface Burning Characteristics of Building Materials , unless the interior of the hood is provided withautomatic fire protection in accordance with 16.3.2.1.9.2 . [ 45: 7.8.1.1]

(B) *

Baffles shall be constructed so that they are unable to be adjusted to materially restrict the volume of air exhausted through the chemical fume hood.[ 45: 7.8.1.3]


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(C) *

Chemical fume hoods shall be provided with a means of preventing overflow of a spill of 0.5 gal (2 L) of liquid. [ 45: 7.8.1.4]

16.3.2.1.7.2 * Chemical Fume Hood Sash Glazing.

The sash, if provided, shall be glazed with material that will provide protection to the operator against the hazards associated with the use of the hood.(See also Annex G.) [ 45: 7.8.2]

16.3.2.1.7.3 * Chemical Fume Hood Sash Closure.

(A)

Chemical fume hood sashes shall be kept closed whenever possible. [ 45: 7.8.3.1]

(B)

When a fume hood is unattended, its sash shall remain fully closed. [ 45: 7.8.3.2]

16.3.2.1.7.4 * Electrical Devices.

(A)

In installations where services and controls are within the hood, additional electrical disconnects shall be located within 50 ft (15 m) of the hood and shallbe accessible and clearly marked. [ 45: 7.8.4.1]

(B)

If electrical receptacles are located external to the hood, no additional electrical disconnect shall be required. [ 45: 7.8.4.2]

16.3.2.1.7.5 Other Hood Services.

(A)

For new installations or modifications of existing installations, controls for chemical fume hood services (gas, air, water, etc.) shall be located external to thehood and within easy reach. [ 45: 7.8.5.1]

(B)

In existing installations where service controls are within the hood, additional shutoffs shall be located within 50 ft (15 m) of the hood and shall beaccessible and clearly marked. [ 45: 7.8.5.2]

16.3.2.1.7.6 Auxiliary Air.

For auxiliary air hoods, auxiliary air shall be introduced exterior to the hood face in such a manner that the airflow does not compromise the protectionprovided by the hood and so that an imbalance of auxiliary air to exhaust air will not pressurize the hood interior. [ 45: 7.8.6]

16.3.2.1.7.7 Hood Proper Function Alarm.

(A) *

A measuring device for indicating that the hood airflow remains within safe design limits shall be provided on each chemical fume hood. [ 45: 7.8.7]

(B) *

The measuring device for hood airflow shall be a permanently installed device and shall provide continuous indication to the hood user of adequate airflowand alert inadequate hood airflow by a combination of an audible and visual alarm. Where an audible alarm could compromise the safety of the user or theresearch, alternative means of alarm shall be considered.. [ 45: 7.8.7.1]

16.3.2.1.8 Chemical Fume Hood Location.

16.3.2.1.8.1 *

Chemical fume hoods shall be located in areas of minimum air turbulence. [ 45: 7.9.1]

16.3.2.1.8.2

Chemical fume hoods shall not be located adjacent to a single means of access to an exit or to high-traffic areas. [ 45: 7.9.2]

16.3.2.1.8.3 *

Work stations not directly related to the chemical fume hood activity shall not be located directly in front of chemical fume hood openings. [ 45: 7.9.3]

16.3.2.1.9 Chemical Fume Hood Fire Protection.

16.3.2.1.9.1 *

Automatic fire protection systems shall not be required in chemical fume hoods or exhaust systems except in the following cases: [ 45: 7.10.1]

(1) If a hazard assessment shows that an automatic extinguishing system is required for the chemical fume hood, then the applicable automatic fireprotection system standard shall be followed. [ 45: 7.10.1(2)]

16.3.2.1.9.2

Automatic fire protection systems, where provided, shall comply with the following standards, as applicable:

(1) NFPA 11, Standard for Low-, Medium-, and High-Expansion Foam

(2) NFPA 12, Standard on Carbon Dioxide Extinguishing Systems

(3) NFPA 12A, Standard on Halon 1301 Fire Extinguishing Systems

(4) NFPA 13, Standard for the Installation of Sprinkler Systems

(5) NFPA 15, Standard for Water Spray Fixed Systems for Fire Protection

(6) NFPA 17, Standard for Dry Chemical Extinguishing Systems

(7) NFPA 17A, Standard for Wet Chemical Extinguishing Systems

(8) NFPA 69, Standard on Explosion Prevention Systems

(9) NFPA 750, Standard on Water Mist Fire Protection Systems

(10)

[ 45: 7.10.2]

* NFPA 2001, Standard on Clean Agent Fire Extinguishing Systems


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(A)

The fire extinguishing system shall be suitable to extinguish fires within the chemical fume hood under the anticipated conditions of use. [ 45: 7.10.2.1]

16.3.2.1.9.3 *

The design and installation of ducts from chemical fume hoods shall be in accordance with NFPA 91, except that specific requirements in NFPA 45 shalltake precedence. [ 45: 7.10.3]

(A) *

Automatic fire dampers shall not be used in laboratory exhaust systems connected to chemical fume hoods. Any exhaust duct conveying fume hoodexhaust through a fire rating shall provide an alternative means of protection equal to or greater that the rating through which the duct passes by one of thefollowing:.

(1) Wrapped or encased with listed or approved materials having a fire-resistance rating equal to the fire rating after exiting the originating firecompartment for a minimum distance of 3.05 m (10 ft.) beyond the opening.

(2) Constructed of materials and supports having a minimum fire resistance rating equal to the fire barrier

[ 45: 7.10.3.1]

(B)

When a branch duct from a fume hood and/or lab exhaust connects to a common riser located in a shaft enclosure that must travel upward, then theconnection shall be made utilizing a separate upturned steel subduct of at least 22 guage and a length of at least 0.56 m (22 in.) prior to joining the risermanifold from each separate branch duct entering the shaft entrance. [ 45: 7.10.3.1.1]

16.3.2.1.9.4

Fire detection and alarm systems shall not be interlocked to automatically shut down chemical fume hood exhaust fans. [ 45: 7.10.4]

16.3.2.1.9.5

Proper door operation for egress shall be maintained when the supply system shuts down and the lab exhaust system operates, creating a pressuredifferential. [ 45: 7.10.5]

16.3.2.1.9.6

Chemical fume hoods equipped with control systems that vary the hood exhaust airflow as the sash opening varies and/or in conjunction with whether thelaboratory room is in use (occupied or unoccupied) shall be equipped with a user-accessible means to attain maximum exhaust hood airflow regardless ofsash position when necessary or desirable to ensure containment and removal of a potential hazard within the hood. [ 45: 7.10.6]

16.3.2.1.9.7 *

Chemical fume hoods shall be installed in a manner that prevents fire or smoke from a fire in the chemical fume hood from spreading into the voids abovethe ceiling. [ 45: 7.10.7]

16.3.2.1.10 Identification of Chemical Fume Hood Systems.

16.3.2.1.10.1 *

Special-use chemical fume hoods and special-use local exhaust systems shall be identified to indicate their intended use. [ 45: 7.13.1]

16.3.2.1.10.2

A sign containing the following information from the last inspection shall be affixed to each hood, or a properly maintained log of all hoods providing thefollowing information shall be maintained:

(1) Inspection interval

(2) Last inspection date

(3) Average face velocity

(4) Location of fan that serves hood

(5) Inspector’s name

[ 45: 7.13.2]


16.3.2.1.11.1 *

When installed or modified and at least annually thereafter, chemical fume hoods, chemical fume hood exhaust systems, and laboratory special exhaustsystems shall be inspected and tested as applicable, as follows:

(1) Visual inspection of the physical condition of the hood interior, sash, and ductwork

(2) Measuring device for hood airflow

(3) Low airflow and loss-of-airflow alarms at each alarm location

(4) Face velocity

(5) Verification of inward airflow over the entire hood face

(6) Changes in work area conditions that might affect hood performance

[ 45: 7.14.1]

16.3.2.1.11.2

Deficiencies in hood performance shall result in immediate suspension of all activities in the hood until the deficiencies can be corrected.

[ 45: 7.14.2]

16.3.2.1.11.3

Chemical fume hood face velocity profile or hood exhaust air quantity shall be checked after any adjustment to the ventilation system balance. [ 45: 7.14.3]

16.3.2.1.11.4 Detectors and Alarms.

Air system flow detectors, if installed, shall be inspected and tested annually. [ 45: 7.13.4.1]


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16.3.2.1.11.5 Fans and Motors.

(A) *

Air supply and exhaust fans, motors, and components shall be inspected at least annually. [ 45: 7.14.5.1]

(B)

Where airflow detectors are not provided or airflow-rate tests are not made, fan belts shall be inspected quarterly; double sheaves and belts shall bepermitted to be inspected semiannually. [ 45: 7.14.5.2]

(C)

Frayed or broken belts shall be replaced promptly. [ 45: 7.14.5.3]

16.3.2.2 Laboratory Operations and Apparatus.

16.3.2.2.1 Operations.

This chapter shall apply to new and existing laboratories [ 45: 11.1]

16.3.2.2.1.1 * Hazards of Chemicals and Chemical Reactions.

(A)

Before laboratory tests or chemical reactions are begun, evaluations shall be made for hazards that can be encountered or generated during the course ofthe work. [ 45: 11.2.1.1]

(B)

Evaluations shall include the hazards associated with the properties and the reactivity of the materials used and any intermediate and end products thatcan be formed, hazards associated with the operation of the equipment at the operating conditions, and hazards associated with the proposed reactions —for example, oxidation and polymerization. [See also 16.3.2.2.1.1(D) .] [ 45: 11.2.1.2]

(C)

Regular reviews of laboratory operations and procedures shall be conducted with special attention given to any change in materials, operations, orpersonnel. [ 45: 11.2.1.3]

(D) *

Where reactions are being performed to synthesize materials, the hazard characteristics of which have not yet been determined by test, precautions shallbe employed to control the highest possible hazard based on a known hazard of similar material. [ 45: 11.2.1.4]

(E)

Where use of a new material might present a severe explosion potential, initial experiments or tests shall be conducted in an enclosure that is designed toprotect people and property from potential explosion damage. (See 16.2.4 .) [ 45: 11.2.1.5]

(F)

Unattended or automatic laboratory operations involving hazardous chemicals shall be provided with regular surveillance for abnormal conditions.[ 45: 11.2.1.6]

(1) Unattended operations shall be provided with override control and automatic shutdown to prevent system failure that can result in fire or explosion.[ 45: 11.2.2.4]

(2) Electrically heated constant temperature baths shall be equipped with over-temperature shutoff switches in addition to normal temperature controls,if overheating could result in a fire or an explosion. [ 45: 11.3.4.1]

16.3.2.2.1.2 Other Operations.

(A)

Other laboratory operations, such as reactions at temperatures and pressures either above or below ambient conditions, shall be conducted in a mannerthat minimizes hazards. [ 45: 11.2.8.1]

(B)

Shielding shall be used whenever there is a reasonable probability of explosion or vigorous chemical reaction and associated hazards during charging,sampling, venting, and discharge of products. (See 16.2.4 and 16.3.2.2.2.3 .) [ 45: 11.2.8.2]

(C)

Glass apparatus containing gas or vapors under vacuum or above ambient pressure shall be shielded, wrapped with tape, or otherwise protected fromshattering (such as engineering controls or by apparatus design) during use. [ 45: 11.2.8.3]

(D) *

Quantities of reactants shall be limited and procedures shall be developed to control or isolate vigorous or exothermic reactions. [ 45: 11.2.8.4]

(E)

[GH 2 ] evolved during drying operations shall be condensed, trapped, or vented to avoid ignition. [ 45: 11.2.8.5]

16.3.2.2.2 Apparatus.

16.3.2.2.2.1 General.

(A)

Apparatus shall be installed in compliance with applicable requirements of NFPA standards, including NFPA 70 . [ 45: 11.13.1.1]

(B)

Operating controls shall be accessible under normal and emergency conditions. [ 45: 11.13.1.2]

16.3.2.2.2.2 Heating Equipment.

(A)

All unattended electrical heating equipment shall be equipped with a manual reset over-temperature shutoff switch, in addition to normal temperaturecontrols, if overheating could result in a fire or explosion. [ 45: 11.3.3.1]


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(B)

Heating equipment with circulation fans or water cooling shall be equipped with an interlock arranged to disconnect current to the heating elements if thefan fails or the water supply is interrupted. [ 45: 11.3.3.2]

(C)

Burners, induction heaters, ovens, furnaces, and other heat-producing equipment shall be located a safe distance from areas where temperature-sensitiveand flammable materials and [GH 2 ] are handled. [ 45: 11.3.3.3]

(D)

Oven and furnace installations shall comply with NFPA 86. [ 45: 11.3.3.4]

16.3.2.2.2.3 Pressure Equipment.

(A) *

Equipment used at pressures above 15 psi (103 kPa gauge) shall be designed and constructed by qualified individuals for use at the expectedtemperature, pressure, and other operating conditions affecting safety. [ 45: 11.3.5.1]

(B)

Pressure equipment shall be fitted with a pressure relief device, such as a rupture disc or a relief valve. The pressure relief device shall be vented to a safelocation. [ 45: 11.3.5.2]

(C)

Equipment operated at pressures above 15 psi (103 kPa gauge), such as autoclaves, steam sterilizers, reactors, and calorimeters, shall be operated andmaintained according to manufacturers’ instructions, the design limitations of the equipment, and applicable codes and regulations. [ 45: 11.3.5.3]

(1) Such equipment shall be inspected on a regular basis. [ 45: 11.3.5.3.1]

(2) Any significant change in the condition of the equipment, such as corrosion, cracks, distortion, scale formation, or general chemical attack, or anyweakening of the closure, or any inability of the equipment to maintain pressure, shall be documented and removed from service immediately andshall not be returned to service until approved by a qualified person. [ 45: 11.3.5.3.2]

(D)

Any pressure equipment that has been found to be degraded shall be derated or discarded, whichever is appropriate. [ 45: 11.3.5.4]

16.3.2.2.2.4 Analytical Instruments.

(A)

Analytical instruments, such as infrared, ultraviolet, atomic absorption, x-ray, mass spectrometers, chromatographs, and thermal analyzers, shall beinstalled in accordance with the manufacturers’ instructions and applicable standards and codes. [ 45: 11.3.6.1]

(B) *

Analytical instruments shall be operated in accordance with manufacturers’ instructions or approved recommended operating procedures. [ 45: 11.3.6.2]

16.3.2.3 Hazard Identification.


16.3.2.3.1 * Exhaust Systems.

Exhaust systems used for the removal of hazardous materials shall be identified to warn personnel of the possible hazards. [ 45: 13.3]

16.3.2.3.2 Identification Systems.

Graphic systems used to identify hazards shall comply with ANSI Z535.1, Safety Color Code ; ANSI Z535.2, Environmental and Facility Safety Signs ;ANSI Z535.3, Criteria for Safety Symbols ; and ANSI Z535.4, Product Safety Signs and Labels ; or other approved graphic systems. [ 45: 13.5]

16.3.3 Outdoor Dispensing. (Reserved)

16.4 Storage.

16.4.1 General.

16.4.1.1 GH 2 and LH 2 in Cylinders.

16.4.1.1.1

Cylinders shall be handled only by trained personnel. (See Annex H.)

16.4.1.1.2 Cylinder Safety.

16.4.1.1.2.1

Cylinders shall be secured in accordance with 7.1.7.4 .

16.4.1.1.2.2

Cylinders in the laboratory shall be equipped with a pressure regulator designed for the specific gas and marked for its maximum cylinder pressure.[ 45: 10.1.5.2]

(A)

The regulator system shall be equipped with two gauges, either on the regulator or remote from the regulator, installed so as to show both the cylinderpressure and the outlet pressure. [ 45: 10.1.5.2.1]

(B)

Where the source cylinder is outside of the laboratory, a station regulator and gauge shall be installed at the point of use to show outlet pressure.[ 45: 10.1.5.2.2]

(C)

Cylinders shall have a manual shutoff valve. A quick connect shall not be used in place of a shutoff valve. [ 45: 10.1.5.3]

16.4.1.2 Storage and Piping Systems.

16.4.1.2.1 *

The method of storage and piping systems for compressed and liquefied gases shall comply with Chapters 4, 6, 7, and 8.


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16.4.1.2.2 *

Each point of use shall have an accessible manual shutoff valve. [ 45: 10.2.3]

16.4.1.2.2.1

The manual shutoff valve at the point of use shall be located away from the potential hazards and be located within 6 ft (1.8 m) of the point of use.[ 45: 10.2.3.1]

16.4.1.2.2.2

Where the cylinder valve is located within immediate reach, a separate point-of-use shutoff valve shall not be required. [ 45: 10.2.3.2]

16.4.1.2.2.3

Line regulators that have their source away from the point of use shall have a manual shutoff valve. [ 45: 10.2.3.3]

16.4.1.2.2.4

An emergency gas shutoff device in an accessible location at the exit shall be provided in addition to the manual point-of-use valve in each educational andinstructional laboratory space that has a piped gas-dispensing valve. [ 45: 10.2.3.4]

16.4.1.2.3

Each and every portion of a piping system shall have uninterruptible pressure relief. [ 45: 10.2.4]

16.4.1.2.3.1

Any part of the system that can be isolated from the rest of the system shall have adequate pressure relief. [ 45: 10.2.4.1]

16.4.1.2.3.2

Piping shall be designed for a pressure greater than the maximum system pressure that can be developed under abnormal conditions. [ 45: 10.2.4.2]

16.4.1.2.3.3

A pressure relief system shall be designed to provide a discharge rate sufficient to avoid further pressure increase and shall vent to a safe location.[ 45: 10.2.4.3]

16.4.1.2.4 *

Permanent piping shall be identified at the supply point and at each discharge point with the name of the material being transported. [ 45: 10.2.5]

16.4.1.2.5 *

Piping systems, including regulators, shall not be used for gases other than those for which they are designed and identified unless a thorough review ofthe design specifications, materials of construction, and service compatibility is made and other appropriate modifications have been made. [ 45: 10.2.6]

16.4.1.3 LH 2 .

16.4.1.3.1

All system components used for cryogenic fluids shall be selected and designed for such service. [ 45: 10.4.1]

16.4.1.3.1.1

Design pressure for vessels and piping shall be not less than 150 percent of maximum pressure relief. [ 45: 10.4.1.1]

16.4.1.3.1.2 *

Systems or apparatus handling a cryogenic fluid that can cause freezing or liquefaction of the surrounding atmosphere shall be designed to prevent contactof the condensed air with organic materials. [ 45: 10.4.1.2]

16.4.1.3.2

Pressure relief of vessels and piping handling cryogenic fluids shall comply with the applicable requirements of 16.4.1.2 . [ 45: 10.4.2]

16.4.1.3.3

The space in which cryogenic systems are located shall be ventilated commensurate with the properties of [LH 2 ]. [ 45: 10.4.3]

16.4.2 Indoor Storage.

Cylinders [-]that are not necessary for current laboratory requirements shall be stored outside the laboratory unit in accordance with Chapters 7 and 9.[ 45: 10.1.2]

16.4.3 Outdoor Storage.

16.4.3.1

[GH 2 ] cylinders installed or stored outside of laboratory buildings shall be installed and operated in accordance with Chapters 1 through 7. [ 45: 10.3.1]

16.4.3.2

Compressed gas delivery systems shall be designed in accordance with Chapters 1 through 7. [ 45: 10.3.2]

Requirements

T he requirements for laboratories handling hydrogen are addressed in NFPA 45.

The requirements for hoods, vents are bottle cabinets are addressed in UL 1805.


I cannot find any hydrogen specific language in this section. This appears to be a straight cut and paste of NFPA 45, “Standard on Fire Protection for Laboratories Using Chemicals”.

In my opinion, this chapter is in violation of the NFPA policy of extracting from codes and referencing standards and should either be deleted outright or have a single line reference to NFPA 45.

Currently, the laboratories have been trained to use NFPA 45 as their safety bible since 1974. Additionally, name a laboratory which only handles hydrogen. And finally, allowing two documents, which may diverge with time, does not help the industry.

I am also surprised that the key product safety standard for laboratories, UL 1805, “Laboratory Hoods and Cabinets”, is not referenced in either code set.

The code writing group might consider recommending the formal adoption of NFPA 45 in the ICC model codes and UL 1805 in both the ICC and NFPA sets of model


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codes.




Street Address:

City:

State:

Zip:



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Chapter 16 Laboratory Operations

16.1 Scope.

The requirements of this chapter shall apply to the storage, use, and handling of GH 2 and LH 2 in laboratories, laboratory buildings, laboratory units, or

laboratory work areas as defined by Chapter 3 .

16.1.1 Application.

16.1.1.1

The requirements of this chapter shall apply to the storage, use, handling, or dispensing of GH 2 in laboratory buildings, laboratory units, and laboratory

work areas, whether located above or below grade, when the amount of GH 2 exceeds 75 scf (2.2 standard m 3 ) or the amount of LH 2 exceeds 1 gal

(3.8 L).

16.1.1.2

The storage, use, and handling of GH 2 in any quantity shall also comply with the requirements of Chapters 1 through 4 and the requirements of

Chapters 5 through 8 , as applicable.

16.1.1.3


16.1.1.4

The use-specific requirements of this chapter for hydrogen in laboratory operations shall apply.

16.1.1.5


16.1.2

This chapter shall not apply to the following:

(1) Laboratory units that contain less than 75 scf (2.2 standard m 3 ) of GH 2 or 1 gal (3.8 L) of LH 2

(2)

(3) Laboratories that are primarily manufacturing plants

(4) Incidental testing facilities

16.2 General.

16.2.1 Means of Access to an Exit.

16.2.1.1 *

A second means of access to an exit shall be provided from a laboratory work area if any of the following situations exist: [ 45: 5.4.1]

(1) A laboratory work area contains an explosion hazard located so that an incident would block escape from or access to the laboratory work area.[ 45: 5.4.1(1)]

(2) A hood in a laboratory work area is located adjacent to the primary means of exit access. [ 45: 5.4.1(4)]

(3) A compressed gas cylinder larger than lecture bottle size [approximately 2 in. × 13 in. (5 cm × 33 cm)] is located such that it could prevent safeegress in the event of accidental release of cylinder contents. [ 45: 5.4.1(5)]

(4) A cryogenic container is located such that it could prevent safe egress in the event of accidental release of container contents. [ 45: 5.4.1(6)]

16.2.1.2

Emergency lighting facilities shall be provided for any laboratory work area requiring a second means of access to an exit, in accordance with 16.2.1.1 .[ 45: 5.4.4]

16.2.1.3

Emergency lighting in laboratory work areas and exits shall be installed in accordance with Section 7.9, Emergency Lighting, of NFPA 101 . [ 45: 5.4.5]

16.2.2 Electrical Installation.

All electrical installations, including wiring and appurtenances, apparatus, lighting, signal systems, alarm systems, remote control systems, or parts thereof,shall comply with NFPA 70 . [ 45: 5.6]

16.2.2.1 *

Laboratory work areas, laboratory units, and chemical fume hood interiors shall be considered as unclassified electrically with respect to Article 500 ofNFPA 70 , unless operations are determined to cause a hazardous atmosphere. [ 45: 5.6.2]

16.2.3 Fire Protection.

16.2.3.1 Automatic Fire Extinguishing Systems.

16.2.3.1.1 Automatic Sprinkler Systems.

16.2.3.1.1.1

A fire protection system shall be provided for laboratories in accordance with Chapter 6 .

16.2.3.1.1.2 *

Fire sprinklers in laboratory units shall be the quick-response (QR) sprinkler type installed in accordance with NFPA 13. [ 45: 6.1.1.2]

* Laboratories that are pilot plants


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16.2.3.1.1.3

Automatic sprinkler systems shall be regularly inspected, tested, and maintained in accordance with NFPA 25. [ 45: 6.1.1.3]

16.2.3.2 Fire Alarm Systems.

16.2.3.2.1

A fire alarm system shall be provided for laboratories in accordance with Chapter 6 .

16.2.3.2.2

The fire alarm system, where provided, shall be designed so that all personnel endangered by the fire condition or a contingent condition shall be alerted.[ 45: 6.4.3]

16.2.3.2.3

The fire alarm system shall alert local emergency responders or the public fire department. [ 45: 6.4.4]

16.2.3.3 Standpipe and Hose Systems.

16.2.3.3.1 *

In all laboratory buildings that are two or more stories above or below the grade level (level of exit discharge), Class I wet pipe standpipesystems shall beinstalled in accordance with NFPA 14. [ 45: 6.2.1]

16.2.3.3.2 *

Standpipe systems shall be regularly inspected, tested, and maintained in accordance with NFPA 25. [ 45: 6.2 2]

16.2.3.4 Portable Fire Extinguishers.

16.2.3.4.1

Portable fire extinguishers shall be installed, located, and maintained in accordance with NFPA 10. [ 45: 6.3.1]

16.2.4 Explosion Hazard Protection.

16.2.4.1

A laboratory work area shall be considered to contain an explosion hazard if an explosion involving hydrogen could result in significant damage to a facilityor serious injuries to personnel within that laboratory work area.

16.2.5 Fire Prevention.

16.2.5.1 Fire Prevention Procedures.

16.2.5.1.1

Fire prevention procedures shall be established for all new and existing laboratories. [ 45: 6.5.1.1]

16.2.5.1.2

Fire prevention procedures shall include, but not be limited to, the following:

(1) Handling and storage of [GH 2 and LH 2 ]

(2) Open flame and spark-producing equipment work permit system

(3) Arrangements and use of portable electric cords

(4) Smoking area controls

[ 45: 6.5.1.2]

16.2.5.2 * Maintenance Procedures.

Maintenance procedures shall be established for all new and established laboratories. [ 45: 6.5.2]

16.2.5.3 * Emergency Plans.

16.2.5.3.1

Plans for laboratory emergencies shall be established for all new and existing laboratories. The emergency action plan shall include the followingprocedures in the event of a chemical emergency, fire, or explosion:

(1) Procedures for sounding the alarm

(2) Procedures for notifying and coordinating with the fire department, governmental agencies, or other emergency responders or contacts, as required

(3) Procedures for evacuating and accounting for personnel, as applicable

(4) Procedures for establishing requirements for rescue and medical duties for those requiring or performing these duties

(5)

(6) Procedures for shutting down and isolating equipment under emergency conditions to include the assignment of personnel responsible formaintaining critical functions or for shutdown of process operations

(7) Appointment and training of personnel to carry out assigned duties, including steps to be taken at the time of initial assignment, as responsibilities orresponse actions change, and at the time anticipated duties change

(8) Alternative measures for occupant safety, when applicable

(9) Aisles designated as necessary for movement of personnel and emergency response

(10) Maintenance of fire protection equipment

(11) Safe procedures for startup to be taken following the abatement of an emergency

[ 400: 7.2.3.2]

16.2.5.3.2 *

Procedures for extinguishing clothing fires shall be established for all new and existing laboratories. [ 45: 6.5.3.2]

* Procedures and schedules for conducting drills


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16.2.5.3.3

All laboratory users, including, but not limited to, instructors and students, shall be trained prior to laboratory use and at least annually thereafter on theemergency plan. [ 45: 6.5.3.3]

16.3 Use.

16.3.1 General.

16.3.1.1 Instructional Laboratories.

Experiments and tests conducted in educational and instructional laboratory units shall be under the direct supervision of an instructor.

16.3.1.2 Cylinders in Use.

16.3.1.2.1

Cylinders, when in use, shall be connected to gas delivery systems designed by a qualified person. [ 45: 10.1.6.1]

16.3.1.2.2

Cylinders shall be attached to an instrument for use by means of a regulator. [ 45: 10.1.6.2]

16.3.1.2.3

A compressed gas cylinder shall be considered to be “in use” if it is in compliance with one of the following:

(1) Connected through a regulator to deliver gas to a laboratory operation

(2) Connected to a manifold being used to deliver gas to a laboratory operation

(3) A single cylinder secured alongside the cylinder described in 16.3.1.2.3 (1) as the reserve cylinder for the cylinder described in 16.3.1.2.3 (1).

[ 45: 10.1.6.3]

16.3.1.2.4

Cylinders not “in use” shall not be stored in the laboratory unit. [ 45: 10.1.6.4]

16.3.2 Indoor Use.

16.3.2.1 Laboratory Ventilating Systems and Hood Requirements.

16.3.2.1.1 * General.

16.3.2.1.1.1

This chapter shall apply to laboratory exhaust systems, including chemical fume hoods, local ventilated enclosures, fume arms, special local exhaustdevices, and other systems for exhausting air from laboratory work areas in which [GH 2 or LH 2 ] are released. [ 45: 7.1.1]

16.3.2.1.1.2

This chapter shall apply to laboratory air supply systems and shall provide requirements for identification, inspection, and maintenance of laboratoryventilation systems and hoods. [ 45: 7.1.2]

16.3.2.1.2 Basic Requirements.

16.3.2.1.2.1 *

Laboratory ventilation systems shall be designed to ensure that fire hazards and risks are minimized. [ 45: 7.2.1]

16.3.2.1.2.2 *

Laboratory units and laboratory hoods in which [GH 2 or LH 2 ] are present shall be continuously ventilated under normal operating conditions. [ 45: 7.2.2]

16.3.2.1.2.3 *

Chemical fume hoods shall not be relied upon to provide explosion (blast) protection unless specifically designed to do so. (See also G.6.4 and G.6.5for further information on explosion-resistant hoods and shields.) [ 45: 7.2.3]

16.3.2.1.2.4

Exhaust and supply systems shall be designed to prevent a pressure differential that would impede egress or ingress when either system fails or during afire or emergency scenario. This design includes reduced operational modes or shutdown of either the supply or exhaust ventilation systems. [ 45: 7.2.5]

16.3.2.1.2.5

The release of [GH 2 ] into the laboratory shall be controlled by enclosure(s) or captured to prevent any flammable concentrations of vapors from reaching

any source of ignition. [ 45: 7.2.6]

16.3.2.1.3 Supply Systems.

16.3.2.1.3.1

Laboratory ventilation systems shall be designed to ensure that [GH 2 ] originating from the laboratory shall not be recirculated. [ 45: 7.3.1]

16.3.2.1.3.2 *

The location and configuration of fresh air intakes shall be chosen so as to avoid drawing in [GH 2 ] or products of combustion coming either from the

laboratory building itself or from other structures and devices. [ 45: 7.3.2]


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16.3.2.1.3.3

The air pressure in the laboratory work areas shall be negative with respect to corridors and non-laboratory areas of the laboratory unit except in thefollowing instances:

(1) Where operations such as those requiring clean rooms preclude a negative pressure relative to surrounding areas, alternate means shall beprovided to prevent escape of the atmosphere in the laboratory work area or unit to the surrounding spaces.

(2) The desired static pressure level with respect to corridors and non-laboratory areas shall be permitted to undergo momentary variations as theventilation system components respond to door openings, changes in chemical fume hood sash positions, and other activities that can for a shortterm affect the static pressure level and its negative relationship.

(3) Laboratory work areas located within a designated electrically classified hazardous area with a positive air pressure system as described inNFPA 496, Chapter 7, Pressurized Control Rooms, shall be permitted to be positive with respect to adjacent corridors.

[ 45: 7.3.3]

16.3.2.1.3.4 *

The location of air supply diffusion devices shall be chosen so as to avoid air currents that would adversely affect the performance of chemical fume hoods,exhaust systems, and fire detection or extinguishing systems. (See 16.2.3.1 , 16.2.3.2 , and 16.3.2.1.8.1 .) [ 45: 7.3.4]

16.3.2.1.4 Exhaust Air Discharge.

16.3.2.1.4.1 *

Air exhausted from chemical fume hoods and other special local exhaust systems shall not be recirculated. (See also 16.3.2.1.3.1 .) [ 45: 7.4.1]

16.3.2.1.4.2 * Energy Conservation Devices.

(A)

If energy conservation devices are used, they shall be designed in accordance with 16.3.2.1.3.1 through 16.3.2.1.3.3 . [ 45: 7.4.2.1]

(B)

Energy conservation devices shall only be used in a laboratory ventilation system when evaluated and approved by a qualified person. These systemsmust meet, or exceed, the criteria established by Section 5.4.7 and Section 5.4.7.1 of ANSI/AIHA Z9.5, 2012, Laboratory Ventilation . Systems thatrecirculate within their respective laboratory area, such as fan coil units for sensible heat loads, are exempt from these requirements. [ 45: 7.4.2.2]

(C)

Energy conservation devices shall be designed and installed in a manner that safely facilitates anticipated service and maintenance requirements and doesnot adversely impact the proper operation of the exhaust system. [ 45: 7.4.2.3]

16.3.2.1.4.3

Air exhausted from laboratory work areas shall not pass unducted through other areas. [ 45: 7.4.3]

16.3.2.1.4.4 *

Air from laboratory units and laboratory work areas in which [GH 2 ] is present shall be continuously discharged through duct systems maintained at a

negative pressure relative to the pressure of normally occupied areas of the building. [ 45: 7.4.4]

16.3.2.1.4.5

Positive pressure portions of the lab hood exhaust systems (e.g., fans, coils, flexible connections, and ductwork) located within the laboratory building shallbe sealed airtight or located in a continuously mechanically ventilated room. [ 45: 7.4.5]

16.3.2.1.4.6

Chemical fume hood face velocities and exhaust volumes shall be sufficient to contain [GH 2 ] generated within the hood and exhaust them outside of the

laboratory building. [ 45: 7.4.6]

16.3.2.1.4.7 *

The hood shall provide containment of the possible hazards and protection for personnel at all times when [GH 2 is] present in the hood. [ 45: 7.4.7]

16.3.2.1.4.8

Special local exhaust systems, such as snorkels or “elephant trunks,” shall have sufficient capture velocities to entrain the [GH 2 ] being released.

[ 45: 7.4.8]

16.3.2.1.4.9 *

Canopy hoods, laminar flow cabinets, and ductless enclosures shall not be used in lieu of chemical fume hoods. [ 45: 7.4.9]

16.3.2.1.4.10

Laminar flow cabinets shall not be used in lieu of chemical fume hoods. [ 45: 7.4.11]

16.3.2.1.4.11 *

Air exhausted from chemical fume hoods and special exhaust systems shall be discharged above the roof at a location, height, and velocity sufficient toprevent re-entry of chemicals and to prevent exposures to personnel. [ 45: 7.4.12]

16.3.2.1.5 Duct Construction for Hoods and Local Exhaust Systems.

16.3.2.1.5.1

Ducts from chemical fume hoods and from local exhaust systems shall be constructed entirely of noncombustible materials except in the following cases:

(1) Flexible ducts of combustible construction shall be permitted to be used for special local exhaust systems within a laboratory work area. (See16.3.2.1.5.2 .)

(2) Combustible ducts shall be permitted to be used if enclosed in a shaft of noncombustible or limited-combustible construction where they passthrough non-laboratory areas or through laboratory units other than the one they serve. (See 16.3.2.1.5.2 .)

(3) Combustible ducts shall be permitted to be used if all areas through which they pass are protected with an approved automatic fire extinguishingsystem, as described in 16.2.3 . (See 16.3.2.1.5.2 .) [ 45: 7.5.1]


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16.3.2.1.5.2

Combustible ducts or duct linings shall have a flame spread index of 25 or less when tested in accordance with ASTM E84 Standard Test Method forSurface Burning Characteristics of Building Materials , or ANSI/UL 723, Standard for Test for Surface Burning Characteristics of Building Materials . Testspecimens shall be of the minimum thickness used in the construction of the duct or duct lining. [ 45: 7.5.2]

16.3.2.1.5.3

Ducts shall be of adequate strength and rigidity to meet the conditions of service and installation requirements and shall be protected against mechanicaldamage. [ 45: 7.5.5]

16.3.2.1.5.4

Materials used for vibration isolation connectors shall comply with 16.3.2.1.5.2 . [ 45: 7.5.6]

16.3.2.1.5.5

Controls and dampers, where required for balancing or control of the exhaust system, shall be of a type that, in event of failure, will fail open to ensurecontinuous draft. (See 16.3.2.1.9.3 through 16.3.2.1.9.5 .) [ 45: 7.5.8]

16.3.2.1.5.6

Hand holes, where installed for damper, sprinkler, or fusible link inspection or resetting and for residue clean-out purposes, shall be equipped with tight-fitting covers provided with substantial fasteners. [ 45: 7.5.9]

16.3.2.1.5.7 Manifolding of Chemical Fume Hood and Ducts.

(A)

Exhaust ducts from each laboratory unit shall be separately ducted to a point outside the building, to a mechanical room, or to a shaft. [ 45: 7.5.10.1]

(B)

Connection to a common chemical fume hood exhaust duct system shall be permitted to occur within a building only in any of the following locations:

(1) A mechanical room, not connected to a shaft, shall be protected in accordance with Table 5.1.1 of NFPA 45.

(2) A shaft or a mechanical room connected to a shaft, shall be protected in accordance with the chapter for protection of vertical openings of NFPA101

(3) A point outside the building

[ 45: 7.5.10.2]

(C)

Exhaust ducts from chemical fume hoods and other exhaust systems within the same laboratory unit shall be permitted to be combined within thatlaboratory unit. (See 16.3.2.1.4.1 .) [ 45: 7.5.10.3]

16.3.2.1.6 Exhausters (Fans), Controls, Velocities, and Discharge.

16.3.2.1.6.1

Fans shall be selected to meet requirements for fire, explosion, and corrosion. [ 45: 7.7.1]

16.3.2.1.6.2

Fans conveying both corrosive and flammable or combustible materials shall be permitted to be lined with or constructed of corrosion-resistant materialshaving a flame spread index of 25 or less when tested in accordance with ASTM E84, Standard Test Method for Surface Burning Characteristics ofBuilding Materials, or ANSI/UL 723, Standard for Test for Surface Burning Characteristics of Building Materials. [ 45: 7.7.2]

16.3.2.1.6.3

Fans shall be located and arranged so as to afford ready access for repairs, cleaning, inspection, and maintenance. [ 45: 7.7.3]

16.3.2.1.6.4 *

Where [GH 2 is] passed through the fans, the rotating element shall be of nonferrous or spark-resistant construction; alternatively, the casing shall be

constructed of or lined with such material. [ 45: 7.7.4]

(A)

Nonferrous or spark-resistant materials shall have a flame spread index of 25 or less when tested in accordance with ASTM E84, Standard Test Methodfor Surface Burning Characteristics of Building Materials, or ANSI/UL 723, Standard for Test for Surface Burning Characteristics of Building Materials.[ 45: 7.7.4.2]

16.3.2.1.6.5

Motors and their controls shall be located outside the location where [GH 2 is] generated or conveyed, unless specifically approved for that location and

use. [ 45: 7.7.5]

16.3.2.1.6.6 *

Fans shall be marked with an arrow or other means to indicate direction of rotation and with the location of chemical fume hoods and exhaust systemsserved. [ 45: 7.7.6]

16.3.2.1.7 Chemical Fume Hood Construction.

(See also 16.3.2.1.2.2 ) [ 45: 7.8]

16.3.2.1.7.1 Chemical Fume Hood Interiors.

(A) *

Materials of construction used for the interiors of new chemical fume hoods or for the modification of the interiors of existing chemical fume hoods shallhave a flame spread index of 25 or less when tested in accordance with ASTM E84, Standard Test Method for Surface Burning Characteristics of BuildingMaterials, or ANSI/UL 723, Standard for Test for Surface Burning Characteristics of Building Materials , unless the interior of the hood is provided withautomatic fire protection in accordance with 16.3.2.1.9.2 . [ 45: 7.8.1.1]

(B) *

Baffles shall be constructed so that they are unable to be adjusted to materially restrict the volume of air exhausted through the chemical fume hood.[ 45: 7.8.1.3]


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(C) *

Chemical fume hoods shall be provided with a means of preventing overflow of a spill of 0.5 gal (2 L) of liquid. [ 45: 7.8.1.4]

16.3.2.1.7.2 * Chemical Fume Hood Sash Glazing.

The sash, if provided, shall be glazed with material that will provide protection to the operator against the hazards associated with the use of the hood.(See also Annex G .) [ 45: 7.8.2]

16.3.2.1.7.3 * Chemical Fume Hood Sash Closure.

(A)

Chemical fume hood sashes shall be kept closed whenever possible. [ 45: 7.8.3.1]

(B)

When a fume hood is unattended, its sash shall remain fully closed. [ 45: 7.8.3.2]

16.3.2.1.7.4 * Electrical Devices.

(A)

In installations where services and controls are within the hood, additional electrical disconnects shall be located within 50 ft (15 m) of the hood and shallbe accessible and clearly marked. [ 45: 7.8.4.1]

(B)

If electrical receptacles are located external to the hood, no additional electrical disconnect shall be required. [ 45: 7.8.4.2]

16.3.2.1.7.5 Other Hood Services.

(A)

For new installations or modifications of existing installations, controls for chemical fume hood services (gas, air, water, etc.) shall be located external to thehood and within easy reach. [ 45: 7.8.5.1]

(B)

In existing installations where service controls are within the hood, additional shutoffs shall be located within 50 ft (15 m) of the hood and shall beaccessible and clearly marked. [ 45: 7.8.5.2]

16.3.2.1.7.6 Auxiliary Air.

For auxiliary air hoods, auxiliary air shall be introduced exterior to the hood face in such a manner that the airflow does not compromise the protectionprovided by the hood and so that an imbalance of auxiliary air to exhaust air will not pressurize the hood interior. [ 45: 7.8.6]

16.3.2.1.7.7 Hood Proper Function Alarm.

(A) *

A measuring device for indicating that the hood airflow remains within safe design limits shall be provided on each chemical fume hood. [ 45: 7.8.7]

(B) *

The measuring device for hood airflow shall be a permanently installed device and shall provide continuous indication to the hood user of adequate airflowand alert inadequate hood airflow by a combination of an audible and visual alarm. Where an audible alarm could compromise the safety of the user or theresearch, alternative means of alarm shall be considered.. [ 45: 7.8.7.1]

16.3.2.1.8 Chemical Fume Hood Location.

16.3.2.1.8.1 *

Chemical fume hoods shall be located in areas of minimum air turbulence. [ 45: 7.9.1]

16.3.2.1.8.2

Chemical fume hoods shall not be located adjacent to a single means of access to an exit or to high-traffic areas. [ 45: 7.9.2]

16.3.2.1.8.3 *

Work stations not directly related to the chemical fume hood activity shall not be located directly in front of chemical fume hood openings. [ 45: 7.9.3]

16.3.2.1.9 Chemical Fume Hood Fire Protection.

16.3.2.1.9.1 *

Automatic fire protection systems shall not be required in chemical fume hoods or exhaust systems except in the following cases: [ 45: 7.10.1]

(1) If a hazard assessment shows that an automatic extinguishing system is required for the chemical fume hood, then the applicable automatic fireprotection system standard shall be followed. [ 45: 7.10.1(2)]

16.3.2.1.9.2

Automatic fire protection systems, where provided, shall comply with the following standards, as applicable:

(1) NFPA 11, Standard for Low-, Medium-, and High-Expansion Foam

(2) NFPA 12, Standard on Carbon Dioxide Extinguishing Systems

(3) NFPA 12A, Standard on Halon 1301 Fire Extinguishing Systems

(4) NFPA 13, Standard for the Installation of Sprinkler Systems

(5) NFPA 15, Standard for Water Spray Fixed Systems for Fire Protection

(6) NFPA 17, Standard for Dry Chemical Extinguishing Systems

(7) NFPA 17A, Standard for Wet Chemical Extinguishing Systems

(8) NFPA 69, Standard on Explosion Prevention Systems

(9) NFPA 750, Standard on Water Mist Fire Protection Systems

(10)

[ 45: 7.10.2]

* NFPA 2001, Standard on Clean Agent Fire Extinguishing Systems


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(A)

The fire extinguishing system shall be suitable to extinguish fires within the chemical fume hood under the anticipated conditions of use. [ 45: 7.10.2.1]

16.3.2.1.9.3 *

The design and installation of ducts from chemical fume hoods shall be in accordance with NFPA 91, except that specific requirements in NFPA 45 shalltake precedence. [ 45: 7.10.3]

(A) *

Automatic fire dampers shall not be used in laboratory exhaust systems connected to chemical fume hoods. Any exhaust duct conveying fume hoodexhaust through a fire rating shall provide an alternative means of protection equal to or greater that the rating through which the duct passes by one of thefollowing:.

(1) Wrapped or encased with listed or approved materials having a fire-resistance rating equal to the fire rating after exiting the originating firecompartment for a minimum distance of 3.05 m (10 ft.) beyond the opening.

(2) Constructed of materials and supports having a minimum fire resistance rating equal to the fire barrier

[ 45: 7.10.3.1]

(B)

When a branch duct from a fume hood and/or lab exhaust connects to a common riser located in a shaft enclosure that must travel upward, then theconnection shall be made utilizing a separate upturned steel subduct of at least 22 guage and a length of at least 0.56 m (22 in.) prior to joining the risermanifold from each separate branch duct entering the shaft entrance. [ 45: 7.10.3.1.1]

16.3.2.1.9.4

Fire detection and alarm systems shall not be interlocked to automatically shut down chemical fume hood exhaust fans. [ 45: 7.10.4]

16.3.2.1.9.5

Proper door operation for egress shall be maintained when the supply system shuts down and the lab exhaust system operates, creating a pressuredifferential. [ 45: 7.10.5]

16.3.2.1.9.6

Chemical fume hoods equipped with control systems that vary the hood exhaust airflow as the sash opening varies and/or in conjunction with whether thelaboratory room is in use (occupied or unoccupied) shall be equipped with a user-accessible means to attain maximum exhaust hood airflow regardless ofsash position when necessary or desirable to ensure containment and removal of a potential hazard within the hood. [ 45: 7.10.6]

16.3.2.1.9.7 *

Chemical fume hoods shall be installed in a manner that prevents fire or smoke from a fire in the chemical fume hood from spreading into the voids abovethe ceiling. [ 45: 7.10.7]

16.3.2.1.10 Identification of Chemical Fume Hood Systems.

16.3.2.1.10.1 *

Special-use chemical fume hoods and special-use local exhaust systems shall be identified to indicate their intended use. [ 45: 7.13.1]

16.3.2.1.10.2

A sign containing the following information from the last inspection shall be affixed to each hood, or a properly maintained log of all hoods providing thefollowing information shall be maintained:

(1) Inspection interval

(2) Last inspection date

(3) Average face velocity

(4) Location of fan that serves hood

(5) Inspector’s name

[ 45: 7.13.2]


16.3.2.1.11.1 *

When installed or modified and at least annually thereafter, chemical fume hoods, chemical fume hood exhaust systems, and laboratory special exhaustsystems shall be inspected and tested as applicable, as follows:

(1) Visual inspection of the physical condition of the hood interior, sash, and ductwork

(2) Measuring device for hood airflow

(3) Low airflow and loss-of-airflow alarms at each alarm location

(4) Face velocity

(5) Verification of inward airflow over the entire hood face

(6) Changes in work area conditions that might affect hood performance

[ 45: 7.14.1]

16.3.2.1.11.2

Deficiencies in hood performance shall result in immediate suspension of all activities in the hood until the deficiencies can be corrected.

[ 45: 7.14.2]

16.3.2.1.11.3

Chemical fume hood face velocity profile or hood exhaust air quantity shall be checked after any adjustment to the ventilation system balance. [ 45: 7.14.3]

16.3.2.1.11.4 Detectors and Alarms.

Air system flow detectors, if installed, shall be inspected and tested annually. [ 45: 7.13.4.1]


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16.3.2.1.11.5 Fans and Motors.

(A) *

Air supply and exhaust fans, motors, and components shall be inspected at least annually. [ 45: 7.14.5.1]

(B)

Where airflow detectors are not provided or airflow-rate tests are not made, fan belts shall be inspected quarterly; double sheaves and belts shall bepermitted to be inspected semiannually. [ 45: 7.14.5.2]

(C)

Frayed or broken belts shall be replaced promptly. [ 45: 7.14.5.3]

16.3.2.2 Laboratory Operations and Apparatus.

16.3.2.2.1 Operations.


16.3.2.2.1.1 * Hazards of Chemicals and Chemical Reactions.

(A)

Before laboratory tests or chemical reactions are begun, evaluations shall be made for hazards that can be encountered or generated during the course ofthe work. [ 45: 11.2.1.1]

(B)

Evaluations shall include the hazards associated with the properties and the reactivity of the materials used and any intermediate and end products thatcan be formed, hazards associated with the operation of the equipment at the operating conditions, and hazards associated with the proposed reactions —for example, oxidation and polymerization. [See also 16.3.2.2.1.1(D) .] [ 45: 11.2.1.2]

(C)

Regular reviews of laboratory operations and procedures shall be conducted with special attention given to any change in materials, operations, orpersonnel. [ 45: 11.2.1.3]

(D) *

Where reactions are being performed to synthesize materials, the hazard characteristics of which have not yet been determined by test, precautions shallbe employed to control the highest possible hazard based on a known hazard of similar material. [ 45: 11.2.1.4]

(E)

Where use of a new material might present a severe explosion potential, initial experiments or tests shall be conducted in an enclosure that is designed toprotect people and property from potential explosion damage. (See 16.2.4 .) [ 45: 11.2.1.5]

(F)

Unattended or automatic laboratory operations involving hazardous chemicals shall be provided with regular surveillance for abnormal conditions.[ 45: 11.2.1.6]

(1) Unattended operations shall be provided with override control and automatic shutdown to prevent system failure that can result in fire or explosion.[ 45: 11.2.2.4]

(2) Electrically heated constant temperature baths shall be equipped with over-temperature shutoff switches in addition to normal temperature controls,if overheating could result in a fire or an explosion. [ 45: 11.3.4.1]

16.3.2.2.1.2 Other Operations.

(A)

Other laboratory operations, such as reactions at temperatures and pressures either above or below ambient conditions, shall be conducted in a mannerthat minimizes hazards. [ 45: 11.2.8.1]

(B)

Shielding shall be used whenever there is a reasonable probability of explosion or vigorous chemical reaction and associated hazards during charging,sampling, venting, and discharge of products. (See 16.2.4 and 16.3.2.2.2.3 .) [ 45: 11.2.8.2]

(C)

Glass apparatus containing gas or vapors under vacuum or above ambient pressure shall be shielded, wrapped with tape, or otherwise protected fromshattering (such as engineering controls or by apparatus design) during use. [ 45: 11.2.8.3]

(D) *

Quantities of reactants shall be limited and procedures shall be developed to control or isolate vigorous or exothermic reactions. [ 45: 11.2.8.4]

(E)

[GH 2 ] evolved during drying operations shall be condensed, trapped, or vented to avoid ignition. [ 45: 11.2.8.5]

16.3.2.2.2 Apparatus.

16.3.2.2.2.1 General.

(A)

Apparatus shall be installed in compliance with applicable requirements of NFPA standards, including NFPA 70 . [ 45: 11.13.1.1]

(B)

Operating controls shall be accessible under normal and emergency conditions. [ 45: 11.13.1.2]

16.3.2.2.2.2 Heating Equipment.

(A)

All unattended electrical heating equipment shall be equipped with a manual reset over-temperature shutoff switch, in addition to normal temperaturecontrols, if overheating could result in a fire or explosion. [ 45: 11.3.3.1]


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(B)

Heating equipment with circulation fans or water cooling shall be equipped with an interlock arranged to disconnect current to the heating elements if thefan fails or the water supply is interrupted. [ 45: 11.3.3.2]

(C)

Burners, induction heaters, ovens, furnaces, and other heat-producing equipment shall be located a safe distance from areas where temperature-sensitiveand flammable materials and [GH 2 ] are handled. [ 45: 11.3.3.3]

(D)

Oven and furnace installations shall comply with NFPA 86. [ 45: 11.3.3.4]

16.3.2.2.2.3 Pressure Equipment.

(A) *

Equipment used at pressures above 15 psi (103 kPa gauge) shall be designed and constructed by qualified individuals for use at the expectedtemperature, pressure, and other operating conditions affecting safety. [ 45: 11.3.5.1]

(B)

Pressure equipment shall be fitted with a pressure relief device, such as a rupture disc or a relief valve. The pressure relief device shall be vented to a safelocation. [ 45: 11.3.5.2]

(C)

Equipment operated at pressures above 15 psi (103 kPa gauge), such as autoclaves, steam sterilizers, reactors, and calorimeters, shall be operated andmaintained according to manufacturers’ instructions, the design limitations of the equipment, and applicable codes and regulations. [ 45: 11.3.5.3]

(1) Such equipment shall be inspected on a regular basis. [ 45: 11.3.5.3.1]

(2) Any significant change in the condition of the equipment, such as corrosion, cracks, distortion, scale formation, or general chemical attack, or anyweakening of the closure, or any inability of the equipment to maintain pressure, shall be documented and removed from service immediately andshall not be returned to service until approved by a qualified person. [ 45: 11.3.5.3.2]

(D)

Any pressure equipment that has been found to be degraded shall be derated or discarded, whichever is appropriate. [ 45: 11.3.5.4]

16.3.2.2.2.4 Analytical Instruments.

(A)

Analytical instruments, such as infrared, ultraviolet, atomic absorption, x-ray, mass spectrometers, chromatographs, and thermal analyzers, shall beinstalled in accordance with the manufacturers’ instructions and applicable standards and codes. [ 45: 11.3.6.1]

(B) *

Analytical instruments shall be operated in accordance with manufacturers’ instructions or approved recommended operating procedures. [ 45: 11.3.6.2]

16.3.2.3 Hazard Identification.


16.3.2.3.1 * Exhaust Systems.

Exhaust systems used for the removal of hazardous materials shall be identified to warn personnel of the possible hazards. [ 45: 13.3]

16.3.2.3.2 Identification Systems.

Graphic systems used to identify hazards shall comply with ANSI Z535.1, Safety Color Code ; ANSI Z535.2, Environmental and Facility Safety Signs ;ANSI Z535.3, Criteria for Safety Symbols ; and ANSI Z535.4, Product Safety Signs and Labels ; or other approved graphic systems. [ 45: 13.5]

16.3.3 Outdoor Dispensing. (Reserved)

16.4 Storage.

16.4.1 General.

16.4.1.1 GH 2 and LH 2 in Cylinders.

16.4.1.1.1

Cylinders shall be handled only by trained personnel. (See Annex H .)

16.4.1.1.2 Cylinder Safety.

16.4.1.1.2.1

Cylinders shall be secured in accordance with 7.1.7.4 .

16.4.1.1.2.2

Cylinders in the laboratory shall be equipped with a pressure regulator designed for the specific gas and marked for its maximum cylinder pressure.[ 45: 10.1.5.2]

(A)

The regulator system shall be equipped with two gauges, either on the regulator or remote from the regulator, installed so as to show both the cylinderpressure and the outlet pressure. [ 45: 10.1.5.2.1]

(B)

Where the source cylinder is outside of the laboratory, a station regulator and gauge shall be installed at the point of use to show outlet pressure.[ 45: 10.1.5.2.2]

(C)

Cylinders shall have a manual shutoff valve. A quick connect shall not be used in place of a shutoff valve. [ 45: 10.1.5.3]

16.4.1.2 Storage and Piping Systems.

16.4.1.2.1 *

The method of storage and piping systems for compressed and liquefied gases shall comply with Chapters 4 , 6 , 7 , and 8 .


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16.4.1.2.2 *

Each point of use shall have an accessible manual shutoff valve. [ 45: 10.2.3]

16.4.1.2.2.1

The manual shutoff valve at the point of use shall be located away from the potential hazards and be located within 6 ft (1.8 m) of the point of use.[ 45: 10.2.3.1]

16.4.1.2.2.2

Where the cylinder valve is located within immediate reach, a separate point-of-use shutoff valve shall not be required. [ 45: 10.2.3.2]

16.4.1.2.2.3

Line regulators that have their source away from the point of use shall have a manual shutoff valve. [ 45: 10.2.3.3]

16.4.1.2.2.4

An emergency gas shutoff device in an accessible location at the exit shall be provided in addition to the manual point-of-use valve in each educational andinstructional laboratory space that has a piped gas-dispensing valve. [ 45: 10.2.3.4]

16.4.1.2.3

Each and every portion of a piping system shall have uninterruptible pressure relief. [ 45: 10.2.4]

16.4.1.2.3.1

Any part of the system that can be isolated from the rest of the system shall have adequate pressure relief. [ 45: 10.2.4.1]

16.4.1.2.3.2

Piping shall be designed for a pressure greater than the maximum system pressure that can be developed under abnormal conditions. [ 45: 10.2.4.2]

16.4.1.2.3.3

A pressure relief system shall be designed to provide a discharge rate sufficient to avoid further pressure increase and shall vent to a safe location.[ 45: 10.2.4.3]

16.4.1.2.4 *

Permanent piping shall be identified at the supply point and at each discharge point with the name of the material being transported. [ 45: 10.2.5]

16.4.1.2.5 *

Piping systems, including regulators, shall not be used for gases other than those for which they are designed and identified unless a thorough review ofthe design specifications, materials of construction, and service compatibility is made and other appropriate modifications have been made. [ 45: 10.2.6]

16.4.1.3 LH 2 .

16.4.1.3.1

All system components used for cryogenic fluids shall be selected and designed for such service. [ 45: 10.4.1]

16.4.1.3.1.1

Design pressure for vessels and piping shall be not less than 150 percent of maximum pressure relief. [ 45: 10.4.1.1]

16.4.1.3.1.2 *

Systems or apparatus handling a cryogenic fluid that can cause freezing or liquefaction of the surrounding atmosphere shall be designed to prevent contactof the condensed air with organic materials. [ 45: 10.4.1.2]

16.4.1.3.2

Pressure relief of vessels and piping handling cryogenic fluids shall comply with the applicable requirements of 16.4.1.2 . [ 45: 10.4.2]

16.4.1.3.3

The space in which cryogenic systems are located shall be ventilated commensurate with the properties of [LH 2 ]. [ 45: 10.4.3]

16.4.2 Indoor Storage.

Cylinders [-]that are not necessary for current laboratory requirements shall be stored outside the laboratory unit in accordance with Chapters 7 and 9 .[ 45: 10.1.2]

16.4.3 Outdoor Storage.

16.4.3.1

[GH 2 ] cylinders installed or stored outside of laboratory buildings shall be installed and operated in accordance with Chapters 1 through 7 . [ 45: 10.3.1]

16.4.3.2

Compressed gas delivery systems shall be designed in accordance with Chapters 1 through 7 . [ 45: 10.3.2]


Reason:Delete entire Chapter.

The inclusion of Chapter 16 does not add any technical benefits and instead creates conflicts with building codes and fire codes adopted by jurisdictions. This appears to be an unnecessary straight cut and paste of NFPA 45, “Standard on Fire Protection for Laboratories Using Chemicals”. All of the necessary safety requirements for the use of hydrogen in labs can be gained by building and fire codes simply referencing the NFPA 2 requirements without this chapter being present.

Moreover, since existing building and fire codes do not refer to NFPA 45, the inclusion of the language adds conflicts that require unnecessary review and determination of applicability. This current code development cycle for the International Fire Code, (the primary fire code applied to new construction and the majority of maintenance fire code adoptions), includes a proposal with some minor references to NFPA 45 and the building and fire code development process is the appropriate venue for inclusion of NFPA 45 requirements.




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16.2.2.1*

Laboratory work areas, laboratory units, and chemical fume hood interiors shall be considered as unclassified electrically with respect to Article 500 [orArticle 505] of NFPA 70, unless operations are determined to cause a hazardous atmosphere. [45:5.6.2]









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17.2* Parking Garages.

17.2.1

The storage of self-propelled vehicles powered by GH2 or LH2 in parking garages or residential garages associated with one- or two-family dwellings shall

be subject to the same requirements applicable to vehicles powered by traditional fuels.

17.2.2 The requirements for indoor parking of vehicles are located within the building and fire prevention codes adopted within a jurisdiction.

The fire hazard presented by self-propelled vehicles powered by GH2 or LH2 is sufficiently similar to those presented by vehicles fueled by liquid gasoline ordiesel fuel that no additional requirements are warranted. Studies and fire tests performed have concluded that the combustible components common to alltypes of automobiles can cause a vehicle fire to spread from one parked vehicle to an adjacent one but that the presence or release of hydrogen (such asthrough activation of a thermal pressure relief device) is not a major cause of fire spread.

Delete - A.17.2 The requirements for indoor parking of vehicles are located within the building and fire prevention codes adopted within a jurisdiction.


17.2.1 What is a condominium complex? Keep it simple, Move A17.2 to 17.2.2. and add "The fire hazard presented by self-propelled vehicles powered by GH2 or LH2 is sufficiently similar to those presented by vehicles fueled by liquid gasoline or diesel fuel that no additional requirements are warranted. Studies and fire tests performed have concluded that the combustible components common to all types of automobiles can cause a vehicle fire to spread from one parked vehicle to an adjacent one but that the presence or release of hydrogen (such as through activation of a thermal pressure relief device) is not a major cause of fire spread.".




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17.2.1

The In addition to complying with all present requirements, the storage of self-propelled vehicles powered by GH2 or LH2 in parking garages or residential

garages associated with one- or two-family dwellings shall be subject to the same requirements applicable to vehicles powered by traditionalfuels. following additional requirements:

17.2.1.1 The garage shall be naturally vented and actively ventilated to prevent a dangerous concentration of hydrogen in the event of hydrogen leaks.

17.2.1.2 No open flame such as a gas fired water heater shall be present in the garage.

17.2.1.3 A DOT flammability label for liquid hydrogen or gaseous hydrogen shall be affixed to the outside of the garage door.

17.2.1.4 The local fire department shall be informed of the intention to garage the LH 2 or GH 2 vehicle before use.



F_Ingle_attachment.pdf Attachment contains the full substantiation which contains pictures and links.


My house, like many in the US is of wood frame construction with tar and gravel roof, with only 16 feet separation wall to wall from the neighbors. A sudden, intense fire in the garage would quickly envelop the house in flame, which would quickly spread to the neighboring houses. Although there is quick response from our local fire department, the house would be beyond saving before the fire department arrives. Three local gas stations in my town have been chosen to be modified for the addition of hydrogen refueling capabilities, to encourage the citizens to purchase hydrogen fueled fuel cell automobiles. Storage of the vehicle in an ordinary attached garage is very likely, and presently requires no permit approval. Note also that many, perhaps most garages contain a natural gas fired water heater. This poses an additional risk of igniting any hydrogen escaping from the vehicle.

Thus, without modification of the garage structure to prevent hydrogen buildup, the addition of sensor systems, and ventilation fans, parking a hydrogen fueled car presents a danger which is neighborhood-wide and threatens us all. One might argue that the probability of the garaged vehicle is small, but I depend heavily on risk management for my job, and the risk is the product of the probability times the damage potential. Hydrogen fueled vehicles are too new for an accurate pictures of the actual risks and probabilities to be established, unlike conventional gasoline powered vehicles. I believe that hydrogen fueled vehicles should be required to be parked at the curb until the historical risks can be determined and mediated. Alternatively, if the hydrogen fueled vehicle is to be parked inside a garage, strong fire prevention standards are required, at least for now. Perhaps over time and with the benefit of experience, future standards can be relaxed.

If there is an overpressure, the relief valve opens, spilling all the contents within ten seconds or so. The discharge is purposely directed upward so that on the road the flame is less likely to damage other vehicles. Attached is a picture of the flame which results from an open relief valve. Note that most of the hydrogen flame is not visible, and extends far above the flame visible in the picture. Think what would happen to the garage roof if this occurred if the vehicle had been inside.

GH2 is a high pressure system. Unless it id damaged, there is a low probability that the tank will burst, since testing based on road hazards during manufacture and periodically later will ensure an adequate safety margin. In addition, there will not be road vibration or vehicle collision while the vehicle is garaged.

An in-tank pressure regulator is included so that the gas lines outside the tank are lower pressure. However, leaks from fittings or imperfections in tank construction may occur. Hydrogen has very low viscosity and it is difficult to ensure that loose fittings or contamination of the seals will allow some loss, particularly after opening the seals during maintenance or testing. If there is a leak, hydrogen will accumulate at the ceiling of the garage.

How safe will it be? Will the car have to bear a DOT safety sticker? If not, why not?

LH2 by contrast is a low pressure system. However, due to the extremely cold temperature of LH2, a continual boil-off must necessarily occur when the vehicle is not in use. As pointed out in the BMW flyer (see attachment) on its LH2 vehicle, challenges remain to be solved. If there are unsolved challenges, are we really ready to release a new NFPA standard which pretends that they have already been solved, when the manufacturer states that they have not? From: https://dps.mn.gov/divisions/sfm/programs-services/Documents/Responder%20Safety/Alternative%20Fuels/FuelCellHydrogenFuelVehicleSafety.pdf

Parking of the vehicle Parking a hydrogen vehicle or other gas-fueled vehicle in an enclosed structure is a serious safety concern as it can lead to a buildup of the gas. Hydrogen’s tendency to rise and disperse rapidly makes this the only situation in which small leaks can create extremely dangerous situations.Detection

The high probability of at least trickling emissions of hydrogen and the lower flammability level of about 6% (hydrogen under normal pressure) leads to the necessity of early detection of even very low concentrations of hydrogen. Sensors to detect concentration of hydrogen below the lower flammability level are currently still very expensive. Odorants that are added to natural gas cannot be easily added to hydrogen or methane used in fuel cells as the larger molecules and especially the sulfur content of current odorants would poison fuel cells. Research is being conducted into the possibility of removing these odorants before the fuel enters the fuel cell. This would leave the fuel cell itself and molecular-sized leaks in the fuel transport system as the only sources of odor-free hydrogen. Odorants are still difficult for detectors to pick up, but they are less expensive than hydrogen detectors.

From: https://courses.engr.illinois.edu/npre470/web/readings/Hydrogen%20safety%20issues.pdf

Hydrogen vehicle hazards Hydrogen onboard a vehicle may pose a safety hazard. The hazards should be considered in situations when vehicle is inoperable… and in collisions. Potential hazards are due to fire, explosion

Hydrogen as a source of fire or explosion may come from the fuel storage… The largest amount of hydrogen at any given time is present in the tank. Several tank failure modes may be considered…

external fire combined with failure of pressure relief device to open; massive leak, due to faulty pressure relief device tripping…operation of pressure relief device in a case of fire (which is the purpose of the device). slow leak due to stress cracks in tank liner, faulty pressure relief device, or faulty coupling from tank to the feed line, or impact-induced openings in fuel line

connection.

A similar failure analysis may be applied to both high pressure and low pressure fuel lines.


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In a study conducted on behalf of Ford Motor Company, Directed Technologies, Inc., has performed a detailed assessment of probabilities of the above failure modes. The conclusion of the study is that a catastrophic rupture is a highly unlikely event. However, several failure modes resulting in large hydrogen release or a slow leak has been identified both in normal operation and in collision. Most of the above discussed failure modes may be either avoided or their occurrence and consequences minimized by:

leak detection by either a leak detector or by adding an odorant to the hydrogen fuel (this may be a problem for fuel cells); designing the system for both active and passive ventilation (such as an opening to allow the hydrogen to escape upward).

From: http://www.google.com/url?sa=t&rct=j&q=&esrc=s&source=web&cd=5&cad=rja&uact=8&ved=0ahUKEwj_6taVnq3NAhUM6GMKHdkDB2MQFgg9MAQ&url=http%3A%2F%2Fwww.nhtsa.gov%2FDOT%2FNHTSA%2FNVS%2FCrashworthiness%2FAlternative%2520Energy%2520Vehicle%2520Systems%2520Safety%2520Research%2F811267.pdf&usg=AFQjCNH6dy4nCx3Lsvx7XZyq6epEFL6zBQ

They also determined that an upward directed vent is not always effective especially in the event of an overturned vehicle or if released in a parking garage.

Thank you for giving me the opportunity to comment on this proposed change to the NFPA.


Submitter Full Name: frank ingle

Organization: instrum for science and med

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Chapter 18 Repair Garage

18.1 Scope

This chapter shall apply to buildings and structures used for service and repair operations in connection with self-propelled vehicles (including, but notlimited to, passenger automobiles, buses, trucks and tractors) in which GH2 or LH2 is used.

18.2 Applicability.

This chapter shall apply to service and repair operations in connection with self-propelled vehicles powered by GH2 or LH2. The storage, use, and handling

of GH2 or LH2 in any quantity shall comply with the requirements of Chapters 1 through 4 and the applicable requirements of Chapters 5 through 8.

Dispensing of GH2 or LH2 shall comply with Chapters 10 and 11.

18.2.1

Major repair facilities that also repair flammable and combustible liquid vehicles shall also meet the requirements of NFPA 30A.

18.2.2

In major repair garages where CNG-fueled vehicles, LNG-fueled vehicles, or LP-Gas–fueled vehicles are also repaired all applicable requirements ofNFPA 52 or NFPA 58, whichever is applicable, shall be met.

18.3 General.

18.3.1 Motor Vehicle Repair Areas.

Repairing of motor vehicles shall be restricted to areas specifically provided for such purposes. [30A:9.7.1]

18.3.1.1

The discharge or defueling of hydrogen from fuel supply containers shall be required for the purpose of fuel storage system modification or repair or whenwelding or open flame activities occur within 18 in. (0.45 m) of the vehicle fuel supply container. Defueling shall be in accordance with Section 18.7.

18.3.1.2

Other than for those repairs listed in 18.3.1.1, repairs that would be required to be performed in a major repair garage shall be permitted to be performed in

a minor repair garage if the vehicle is defueled in accordance with Section 18.7 to less than 200 scf (5.7 Nm3) and the fuel supply container is sealed.

18.3.2 Automatic Sprinkler Systems.

Automatic sprinkler systems shall be provided in accordance with the building code and the fire code adopted by the AHJ.

18.3.3 Gas Detection System.

Major repair garages shall be provided with an approved hydrogen gas detection system such that gas can be detected where vehicle hydrogen fuelstorage systems are serviced or indoor defueling occurs.

18.3.3.1

The detection system shall be maintained and calibrated in accordance with the manufacturer's instructions on at least an annual basis, or more often, ifrequired by the manufacturer.

18.3.3.2

The repair garage operator shall maintain a record of detection system maintenance and calibration in good condition and accessible to an inspector.

18.3.3.3

The hydrogen detection system shall be designed to activate when the level of hydrogen exceeds 25 percent of the lower flammable limit.

18.3.3.4 Location.

System shall provide coverage of the fuel cell vehicle service area. The hydrogen detection system shall have sensors in the following locations:

(1) At inlets to exhaust systems

(2) At high points in service bays with natural ventilation near vents

(3) At the inlets to mechanical ventilation systems; where hydrogen vehicle fuel systems are serviced or defueled.

18.3.3.5

Activation of hydrogen detection system shall result in all of the following:

(1) Initiation of distinct audible and visual alarm signals in the repair garage

(2) Deactivation of heating systems located in the repair garage

(3) Activation of the exhaust system, unless the exhaust system is in continuous operation

18.3.3.6

Failure of the hydrogen detection system shall result in the deactivation of the heating system and activation of the exhaust system and shall cause atrouble signal to sound in an approved location.

18.3.3.7

The circuits of the detection system required by 18.3.3.6 shall be monitored for integrity in accordance with, NFPA 72.

18.4 Exhaust System.

In major repair garages, or where indoor defueling occurs exhaust duct openings shall be located so that they effectively remove hydrogen accumulation atceiling level from all parts of the room.

18.4.1

The exhaust system should be designed per the mechanical code adopted by the AHJ.

18.5 Heat-Producing Appliances.


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18.5.1

Heat-producing appliances shall be installed to meet the requirements of NFPA 31, NFPA 54, NFPA 82, NFPA 90A, and NFPA 211, as applicable, except ashereinafter specifically provided. [30A:7.6.9]

18.5.2

Heat-producing appliances shall be of an approved type. Solid- fuel stoves, improvised furnaces, salamanders, or space heaters shall not be permitted inmajor repair garages or where indoor refueling occurs.

18.5.3

Heat-producing appliances in major repair garages shall be permitted to be installed in a special room that is separated from the repair area by walls thatare constructed to prevent the transmission of hydrogen, that have a fire resistance rating of at least 1 hour, and that have no openings in the walls that leadto a classified area. Specific small openings through the wall, such as for piping and electrical conduit, shall be permitted, provided the gaps and voids arefilled with a fire-resistant material to resist transmission of hydrogen. All air for combustion purposes shall be taken from outside the building.

18.5.4

Heat-producing appliances using gas or oil fuel shall be permitted to be installed in a major repair garage provided the combustion chamber is at least 18 in.(455 mm) below the ceiling.

18.5.5

In major repairs garages, open-flame heaters or heating equipment with exposed surfaces having a temperature in excess of 750°F (399°C) shall not bepermitted in areas subject to ignitible concentrations of gas.

18.5.6

Electrical heat-producing appliances shall meet the requirements of Chapter 6.

18.6 Welding and Open-Flame Operations.

18.6.1

Operations involving open flame or electric arcs, including fusion gas and electric welding, shall be restricted to areas specifically provided for suchpurposes. Cutting and welding and related fire prevention precautions shall be in accordance with the requirements of NFPA 51B. [30A:9.7.2.1]

18.6.2

Electric arc welding generators or transformers shall conform to NFPA 70. Gas fusion welding apparatus and storage of compressed gas cylinders shall bein accordance with the provisions of NFPA 51. [30A:9.7.2.2]

18.6.3

The grounded side of an electric welding circuit shall be attached to the part being welded. [30A:9.7.2.3]

18.6.4

Gas fusion welding equipment shall be periodically inspected for worn or injured hoses and defective or damaged valves, gauges, and reducing devices.[30A:9.7.2.5]


18.7.1 Methods of Discharge.

The discharge of hydrogen from motor vehicle fuel storage tanks shall be accomplished through an approved method of atmospheric venting in accordancewith 18.7.1 through 18.7.6.

18.7.2 Defueling Equipment Required at Vehicle Maintenance and Repair Facilities.

Major repair garages shall have equipment to defuel vehicle fuel supply containers. Equipment used for defueling shall be listed and labeled for theintended use.

18.7.3 Manufacturer Equipment Required.

Equipment supplied by the vehicle manufacturer shall be used to connect the vehicle fuel supply containers to be defueled to the defueling system.

18.7.4 Isolated Use.

The defueling shall not be connected to another venting system used for any other purpose.

18.7.5

Defueling systems shall discharge to a safe location in accordance with the requirements of CGA-G-5.5, Hydrogen Vent Systems.

18.7.6 Grounding and Bonding.

The defueling system shall include a method of grounding and bonding and operator instructions to facilitate safe use. The defueling nozzle of the vehiclestorage tank system shall be bonded with the defueling system prior to the commencement of discharge or defueling operations.

18.X Electrical Installations

18.5.1 General Requirements. Electrical wiring and electrical utilization equipment shall be of a type specified by and shall be installed in accordance withNFPA 30A, NFPA 70, National Electrical Code, and Chapter 18.5. Electrical wiring and electrical utilization equipment shall be approved for the locations inwhich they are installed.

18.5.1 Motor vehicle repair rooms, motor vehicle repair booths, or motor vehicle repair spaces where hydrogen vehicles are repaired, the area within455mm (18 in.) of the ceiling shall be designated a Class I, Division 2 hazardous (classified) location.

Exception: motor vehicle repair rooms, motor vehicle repair booths, or motor vehicle repair spaces, this requirement shall not apply where continuousventilation rates meets the requirements in 18.4.X [see exhaust PI]

Areas adjacent to classified locations where flammable vapors are not likely to be released, such as stock rooms, switchboard rooms, and other similarlocations, where mechanically and continuously ventilated at a rate of four or more air changes per hour or designed with positive air pressure, or whereeffectively cut off by walls or partitions shall be designated unclassified



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NFPA2 currently has no electrical requirements specific for repair garages. This proposal uses language from NFPA30A to establish these electrical requirements. The edited text shows the changes from NFPA30A in order to better apply to hydrogen, including applying the new, proposed exhaust flow rates (see exhaust PI). I recommend this section go near 18.4



Public Input No. 151-NFPA 2-2016 [Section No. 18.4] Reference to this PI





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18.1 Scope


18.2 Applicability.




18.2.1


18.2.2


18.3 General.



18.3.1.1


18.3.1.2







18.3.3.1


18.3.3.2


18.3.3.3


18.3.3.4 Location.





18.3.3.5





18.3.3.6


18.3.3.7




18.4.1




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18.5.1


18.5.2


18.5.3


18.5.4


18.5.5


18.5.6



18.6.1


18.6.2


18.6.3


18.6.4











18.7.5




18.A Spray Painting and Undercoating. Spray painting and undercoating spray operations shall be in accordance with the requirements of NFPA 30A.

18.B Drying Apparatus. Drying and baking apparatus shall be in accordance with the requirements of NFPA 30A.

18.C Parts Cleaning shall be in accordance with the requirements of NFPA 30A.

18.D Chassis Cleaning shall be in accordance with the requirements of NFPA 30A.

18.E Housekeeping shall be in accordance with the requirements of NFPA 30A.


The NFPA2/NFPA30A task force proposes that NFPA2 add references to NFPA30A for standard repair garage operations.



Public Input No. 147-NFPA 2-2016 [Sections 18.2.1, 18.2.2] Informative




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18.1 Scope


18.2 Applicability.




18.2.1


18.2.2


18.3 General.



18.3.1.1


18.3.1.2







18.3.3.1


18.3.3.2


18.3.3.3


18.3.3.4 Location.





18.3.3.5





18.3.3.6


18.3.3.7




18.4.1




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18.5.1


18.5.2


18.5.3


18.5.4


18.5.5


18.5.6



18.6.1


18.6.2


18.6.3


18.6.4











18.7.5




18.X Storage and Handling of Flammable and Combustible Liquids, Liquefied Petroleum Gases, and Other Flammable Gases. Except asotherwise provided by this code, the storage and handling of flammable and combustible liquids shall be in accordance with NFPA30, Flammable andCombustible Liquids Code. The storage and handling of liquefied petroleum gas shall be in accordance with NFPA 58, Liquefied Petroleum Gas Code. Thestorage and handling of flammable compressed gas fuels shall be in accordance with NFPA 55, Compressed Gases and Cryogenic Fluids Code, andNFPA 52, Vehicular Gaseous Fuel Systems Code. [30A 9.7.8]

18.X.1 Storage and Handling of Hydrogen Except as otherwise provided by this code, the storage and handling of flammable and combustible liquidsshall be in accordance with Chapters 6 and 7.


This proposal adds requirements for storage and handling of hazardous materials. 18.12 extracts text from NFPA 30A. 18.12.1 provides requirements for hydrogen and references Chapters 6 and 7.





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Repair room, booth or area

18.2.3 Requirements for major repair garages used for service and repair operations in connection with self-propelled vehicles in which GH2 or LH2 is usedshall be permitted to be limited to rooms, booths or areas constructed in accordance with the applicable requirements of 18.2.3.1 through 18.2.3.918.2.3.1 Walls and Ceilings. Walls, doors, and ceilings that intersect or enclose a repair area shall be constructed of noncombustible or limited-combustiblematerials or assemblies and shall be securely and rigidly mounted or fastened. The interior surfaces of the repair area shall be smooth, designed andinstalled to facilitate ventilation. 18.2.3.2 If walls or ceiling assemblies are constructed of sheet metal, single-skin assemblies shall be no thinner than 1.2 mm (0.0478 in.), and each sheetof double-skin assemblies shall be no thinner than 0.9 mm (0.0359 in.). 18.2.3.3 Structural sections of repair booths shall be permitted to be sealed with a caulk or sealant to minimize air leakage. 18.2.3.4 Repair rooms shall be constructed of and separated from surrounding areas of the building by construction assemblies that have a fire resistancerating of 1 hour. 18.2.3.5 Enclosed repair booths and repair rooms shall be provided with means of egress that meet the applicable requirements of Chapter 40 of NFPA101. 18.2.3.6 Separation from Other Operations. Repair booths shall be separated from other operations by a minimum distance of 915 mm (3 ft) or by apartition, wall, or floor/ceiling assembly having a minimum fire resistance rating of 1 hour. Multiple connected repair booths shall not be considered as “otheroperations”. 18.2.3.7 A clear space of not less than 915 mm (3 ft) shall be maintained on all sides and above the repair booth. This clear space shall be kept free of anystorage or combustible construction. 18.2.3.8 This requirement shall not prohibit locating a repair booth closer than 915 mm (3 ft) to or directly against an interior partition, wall, or floor/ceilingassembly that has a fire resistance rating of not less than 1 hour, provided the repair booth can be maintained. 18.2.3.9 This requirement shall not prohibit locating a repair booth closer than 915 mm (3 ft) to an exterior wall or a roof assembly, provided the wall or roofis constructed of noncombustible material and provided the repair booth can be maintained.


The purpose of this proposal is to limit the impact of application of the enhanced requirements necessary for the repair of vehicles fueled by hydrogen, i.e., ‘major repair garages’.

Based upon current provisions of NFPA2 and related codes an entire motor vehicle repair facility must be constructed or renovated to meet these increased requirements even if a single bay space out of many is all that is required to service such vehicles.

The new language provides that the requirements apply to the room, which could be the entire service bay area or a smaller separated room, to a motor vehicle repair booth, or a motor vehicle repair area. The requirements for the major repair garage room/booth/area options have been copied from relevant portions of existing language in NFPA 33 that are applied to spray finishing. The concept is the same, limit any increased hazard to a specific space (room/booth/area) and protect that limited area. The major repair garage booth could be prefabricated or field constructed as long as it meets the specified requirements.

This new option enhances the ease of acceptance of hydrogen as an alternative motor fuel while properly addressing the additional hazards the repair and servicing of these vehicles may present with no reduction in the level of protection currently required to be met.

Source

NFPA 33

Chapter 5 Construction and Design of Spray Areas, Spray Rooms, and Spray Booths

5.1* Walls and Ceilings. Walls, doors, and ceilings that intersect or enclose a spray area shall be constructed of noncombustible or limited-combustible materials or assemblies and shall be securely and rigidly mounted or fastened. The interior surfaces of the spray area shall be smooth, designed and installed to prevent pockets that can trap residues, and designed to facilitate ventilation and cleaning.

5.1.1 Air intake filters that are a part of a wall or ceiling assembly shall be listed as Class 1 or Class 2, in accordance with ANSI/UL 900, Standard for Air Filter Units.

5.1.2 The floor of the spray area shall be constructed of noncombustible material, limited-combustible material, or combustible material that is completely covered by noncombustible material.

5.1.3 Aluminum shall not be used for structural support members or the walls or ceiling of a spray booth or spray room enclosure. Aluminum also shall not be used for ventilation ductwork associated with a spray booth or spray room. Aluminum shall be permitted to be used for interior components, such as platforms, spray apparatus components, and other ancillary devices.

5.1.4 If walls or ceiling assemblies are constructed of sheet metal, single-skin assemblies shall be no thinner than 1.2 mm (0.0478 in.), and each sheet of double-skin assemblies shall be no thinner than 0.9 mm (0.0359 in.).

5.1.5 Structural sections of spray booths shall be permitted to be sealed with a caulk or sealant to minimize air leakage.

5.1.6 Spray rooms shall be constructed of and separated from surrounding areas of the building by construction assemblies that have a fire resistance rating of 1 hour.

5.1.7 Enclosed spray booths and spray rooms shall be provided with means of egress that meet the applicable requirements of Chapter 40 of NFPA 101.

5.3* Separation from Other Operations. Spray booths shall be separated from other operations by a minimum distance of 915 mm (3 ft) or by a partition, wall, or


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floor/ceiling assembly having a minimum fire resistance rating of 1 hour. Multiple connected spray booths shall not be considered as “other operations” except as provided for in Section 13.3.

5.3.1 Spray booths shall be installed so that all parts of the booth are readily accessible for cleaning.

5.3.2 A clear space of not less than 915 mm (3 ft) shall be maintained on all sides and above the spray booth. This clear space shall be kept free of any storage or combustible construction.

5.3.2.1 This requirement shall not prohibit locating a spray booth closer than 915 mm (3 ft) to or directly against an interior partition, wall, or floor/ceiling assembly that has a fire resistance rating of not less than 1 hour, provided the spray booth can be maintained and cleaned.

5.3.2.2 This requirement shall not prohibit locating a spray booth closer than 915 mm (3 ft) to an exterior wall or a roof assembly, provided the wall or roof is constructed of noncombustible material and provided the spray booth can be maintained and cleaned.





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18.2 Applicability.




18.2.1


18.2.2

In major repair garages where CNG-fueled vehicles, LNG-fueled vehicles, or LP-Gas–fueled vehicles are also repaired all applicable requirements of fromNFPA 52 or and NFPA 58 , whichever is applicable, shall be met.


This not an exception but rather an additional requirement




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Public Input No. 147-NFPA 2-2016 [ Sections 18.2.1, 18.2.2 ]

Sections 18.2.1, 18.2.2

18.2.1

Major repair facilities that also repair vehicles powered by flammable and combustible liquid vehicles liquids , CNG, LNG, or LP-Gas shall also meet therequirements of NFPA 30A.

18.2.2

In major repair garages where CNG-fueled vehicles, LNG-fueled vehicles, or LP-Gas–fueled vehicles are also repaired all applicable requirements ofNFPA 52 or NFPA 58, whichever is applicable, shall be met Minor repair garages shall only need to meet the requirements of NFPA 30A .


This proposal was developed by a joint NFPA2/NFPA30A task force to address how hydrogen repair garages are addressed in the two documents. The task force decided to place all of the hydrogen repair garage requirements in NFPA2 while keeping other fuels in NFPA30A. Repair garages that service vehicles which use CNG, LNG, or LP-Gas must meet the requirements in NFPA30A which include requirements to meet NFPA 52 or NFPA 58 whichever is applicable. Minor repair garages for hydrogen vehicles that do not service fuel systems only need to meet NFPA30A since there is no risk for leaks.




Public Input No. 154-NFPA 2-2016 [Section No. 18.6]

Public Input No. 155-NFPA 2-2016 [Chapter 18]





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18.3 General.



18.3.1.1

The discharge or defueling of hydrogen from fuel supply containers shall be required for the purpose of fuel storage system removal, modification or repairor when welding or open flame activities occur within 18 in. (0.45 m) of the vehicle fuel supply container. Defueling shall be in accordance withSection 18.7.

18.3.1.2







18.3.3.1


18.3.3.2


18.3.3.3


18.3.3.4 Location.





18.3.3.5





18.3.3.6


18.3.3.7



Defuel if you disturb the fuel system (i.e. potentially breach containment).

Car guys don't repair. They remove and replace.




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18.3.3.X Repair garages used for the servicing of other gaseous fuel vehicles shall be in accordance with NFPA 30A.


This proposal was developed by a joint NFPA2/NFPA30A task force to address how hydrogen repair garages are addressed in the two documents. The task force decided to place all of the hydrogen repair garage requirements in NFPA2 while keeping other fuels in NFPA30A. Repair garages that service vehicles which use other gaseous fuels must meet the requirements in NFPA30A.



Public Input No. 147-NFPA 2-2016 [Sections 18.2.1, 18.2.2]





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18.3.3.1


18.3.3.2


18.3.3.3


18.3.3.4 Location.





18.3.3.5



(2) Deactivation of modular heating systems located in the repair garage

Activation

Exceptions: Heating by central forced hot air, hot water, and/or steam (i.e. remote furnace, boiler and/or heat pump).


18.3.3.6


18.3.3.7



Not every garage, especially in the northern tier of the US is heated by a modular gas or resistance heater.




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18.4

Exhaust System. In major repair garages, orHeating, Ventilating, and Air Conditioning.

18.4.1 Forced air heating, air-conditioning, and ventilating systems serving a fuel dispensing area inside a building or a repair garage shall not beinterconnected with any such systems serving other occupancies in the building. Such systems shall be installed in accordance with NFPA90A, Standard forthe Installation of Air-Conditioning and Ventilating Systems. [30A: 7.5.1]

18.4.2 Return air openings in areas of motor vehicle repair room, motor vehicle repair booth, or motor vehicle repair space used for the repair or servicing ofhydrogen vehicles shall be not less than 455 mm (18 in.) below the ceiling level measured to the bottom of the openings.

18.4.3 Combined ventilation and heating systems shall not recirculate air from areas that are below grade level.

18.4.4 Exhaust System. Each motor vehicle repair room, motor vehicle repair booth, or motor vehicle repair space for hydrogen vehicles shall be providedwith an approved mechanical ventilation system.

18.4.1 Design The exhaust system should be designed per the mechanical code adopted by the AHJ.

Exception: Where approved by the code official, natural ventilation shall be permitted in lieu of mechanical exhaust ventilation.

18.4.1.1 In each motor vehicle repair room, motor vehicle repair booth, or motor vehicle repair space, or where indoor defueling occurs exhaust ductopenings shall be located so that they effectively remove hydrogen accumulation at ceiling level from all parts of the room. The inlets and outlets for theexhaust shall be arranged as uniformly as possible. The inlets shall be near the floor level, and the exhaust near the high point of the room or the ceiling.

18.4.

1 3 Operation The exhaust

system should be designed per the mechanical code adopted by the AHJ.ventilation rate shall be a minimum of 1 cubic foot per minute per 12 cubic feet of room volume. The ventilation shall be continuous unless interlocked withthe gas detection system as discussed in 18.3.3.5.


This proposal attempts to enhance the HVAC and exhaust equipment requirements as well as attempting to align with NFPA 30A and IFC. The previous text had almost no guidance for the AHJ. The proposal adds guidance on the requirements and location of the HVAC. It also adds detailed requirements on the exhaust system where none existed. The exhaust ventilation rate is the same for a 12 foot tall room (Old: 1 ft3 per minute per square foot of floor area. New: 1 ft3 per minute for 12 cubic foot of room volume)



Public Input No. 153-NFPA 2-2016 [Chapter 18]






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18.4.1

The exhaust system should be designed per the mechanical code adopted by the AHJ. shall be in accordance with Section 6.17 .




This proposal is intended to correlate the various exhaust ventilation requirements by adding some of the later design material to Section 6.17 to enhance the core design parameters, adding pointers to Section 6.17 where lacking, deleting overlapping or otherwise unnecessary language and leaving additional requirements specific to the type of system ventilated in those areas of NFPA 2








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18.5.1

Heat-producing appliances shall be installed to meet the requirements of NFPA 31, NFPA 54, NFPA 82, NFPA 90A, and NFPA 211, as applicable, exceptas hereinafter specifically provided. [ 30A: 7.6.9] shall be in accordance with the requirements NFPA 30A and this chapter.

18.5.2


18.5.3

Heat-producing appliances in major repair garages shall be permitted to be installed in a special room that is separated from the repair area by walls thatare constructed to prevent the transmission of hydrogen, that have a fire resistance rating of at least 1 hour, and that have no openings in the walls thatlead to a classified area. Specific small openings through the wall, such as for piping and electrical conduit, shall be permitted, provided the gaps and voidsare filled with a fire-resistant material to resist transmission of hydrogen. All air for combustion purposes shall be taken from outside the building.

18.5.4

Heat-producing appliances using gas or oil fuel shall be permitted to be installed in a major repair garage provided the combustion chamber is at least18 in. (455 mm) below the ceiling.

18.5.5

In major repairs garages, open- Where major repairs are conducted on hydrogen vehicles, open flame heaters or heating equipment with exposedsurfaces having a temperature in excess of 399°C ( 750°F (399°C ) shall not be permitted within 18 in . (455 mm) of the ceiling or in areas subject toignitible ignitable concentrations of gas.

18.5.6



NFPA 30A has some updates to the Heat Producing Appliances section which was not captured in NFPA2 2016. Instead of extracting this text from NFPA30A this proposal provides a references. It also has additional requirements including specifying the location of the heating system 18 inches below ceiling and reference to Chapter 6 for electrical heating systems.





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18.6.1

Operations involving open flame or electric arcs, including fusion gas and electric welding, shall be restricted to areas specifically provided for suchpurposes. Cutting and welding and related fire prevention precautions shall be in accordance with the requirements of NFPA 51B. [ 30A: 9.7.2.1]

18.6.2

Electric arc welding generators or transformers shall conform to NFPA 70 . Gas fusion welding apparatus and storage of compressed gas cylinders shallbe in accordance with the provisions of NFPA 51. [ 30A: 9.7.2.2]

18.6.3

The grounded side of an electric welding circuit shall be attached to the part being welded. [ 30A: 9.7.2.3]

18.6.4

Gas fusion welding equipment shall be periodically inspected for worn or injured hoses and defective or damaged valves, gauges, and reducing devices.[ 30A: 9.7.2.5]

Welding and Open-Flame Operations shall meet the requirements of NFPA 30A


This proposal simply provides a reference to NFPA30A rather than extracting text. The current text misses some important requirements on welding cylinders. The NFPA2/30A task force agrees that NFPA2 should point to NFPA 30A for generic repair garage operations.



Public Input No. 147-NFPA 2-2016 [Sections 18.2.1, 18.2.2] Informative information





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18.7

Defueling Systems.


The discharge of hydrogen from motor vehicleDefueling equipment Facilities for repairing or replacing hydrogen fuel tanks on hydrogen-fueled vehicles shall have equipment to defuel vehicle storagetanks. Where work must be performed on a vehicle's fuel storage tank for the purpose of maintenance, repair or cylinder certification, defueling and purgingshall be conducted in accordance with this section, Chapters 7 and 8.

Exception: The fuel supply piping from the fuel storage tank to the engine compartment on a motor vehicle or forklift.

18.7.1 Applicability The requirements in this section apply to the defueling equipment and do not apply to the vehicle.

18.7.2 Documented procedure . A documented procedure that explains the logic sequence for defueling or discharging operations shall be maintainedon site and shall be provided to the AHJ upon request. The procedure shall include what actions the operator is required to take in the event of alow-pressure or high-pressure hydrogen release during discharging activity.

Schematic design documents shall be maintained on site illustrating the arrangement of piping, regulators and equipment settings. The schematic shallillustrate the piping and regulator arrangement and shall be shown in spatial relation to the location of the vehicle being defueled and, if applicable, to thecompressor, storage vessels and emergency shutdown devices.

18.7.3 Methods of discharge. The discharge of hydrogen from fuel storage tanks shall be accomplished through a closed transfer system in accordancewith 18.7.3 or an approved method of atmospheric venting in accordance with Section 18.7.

1 through4.

18.7.

6.


Major repair garages shall have equipment to defuel vehicle fuel supply containers.4 Closed transfer system . A documented procedure that explains the logic sequence for discharging the storage tank shall be provided to the fire codeofficial for review and approval. The procedure shall include what actions the operator is required to take in the event of a low-pressure or high-pressurehydrogen release during discharging activity. Schematic design documents shall be provided illustrating the arrangement of piping, regulators and equipmentsettings. The construction documents shall illustrate the piping and regulator a rangement and shall be shown in spatial relation to the location of thecompressor, storage vessels and emergency shutdown devices.

18.7.5 Atmospheric venting of hydrogen from fuel storage containers. Where atmospheric venting is used for the discharge of hydrogen from fuelstorage tanks, such venting shall be in accordance with Sections 18.7.4.1 to 18.7.4.10.

18.7.5.1 Atmospheric defueling equipment. Equipment used for defueling shall be listed and labeled or approved for the intended use.

18.7.

3 Manufacturer Equipment Required.5.2 Manufacturer’s equipment required . Equipment supplied by the

vehiclemanufacturer shall be used to connect the

vehicle fuel supply containersstorage tanks to be defueled to the

defuelingvent pipe system.

18.7.

4 Isolated Use. The defueling5.3 Vent Pipe Defueling vent pipes shall discharge to a safe location in accordance with the requirements of section 6 and 7.

18.7.5.3.1 Vent pipe maximum diameter. Defueling vent pipes shall have a maximum inside diameter of 1 inch (25 mm).

18.7.5.3.2 Isolated use. The defueling vent pipe used shall not be connected to another venting system used for any other purpose.

18.7.5

Defueling systems shall discharge to a safe location in accordance with the requirements of CGA-G-5.5, Hydrogen Vent Systems .


The defueling system shall include a method of grounding and bonding and operator instructions to facilitate safe use. The defueling nozzle of the vehiclestorage tank system.6 Construction documents . Construction documents shall be provided illustrating the defueling system to be utilized. Plan details shall be of sufficientdetail and clarity to allow for evaluation of the piping and control systems to be utilized and include the method of support for cylinders, containers or tanks tobe used as part of a closed transfer system, the method of grounding and bonding and other requirements specified herein.

18.7.5.7 Stability of cylinders, containers and tanks . A method of rigidly supporting cylinders, containers or tanks used during the closed transfersystem discharge or defueling of hydrogen shall be provided. The method shall provide not less than two points of support and shall be designed to resistlateral movement of the receiving cylinder, container or tank. The system shall be designed to resist movement of the receiver based on the highest gasrelease velocity through valve orifices at the receiver’s rated service pressure and volume. Supporting structures or appurtenances used to support receiversshall be constructed of noncombustible materials in accordance with NFPA1, International Building Code, or applicable local code. Tanks mounted invehicles meet this requirement provided the vehicle is secured from moving.

18.7.5.8 Grounding and bonding . Cylinders, containers or tanks and piping systems used for defueling shall be bonded and grounded. Structures orappurtenances used for supporting the cylinders, with NFPA 70. The valve of the vehicle storage tank shall be bonded with the defueling system prior to thecommencement of discharge or defueling operations.



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This proposal recommends replacing the existing text on “Defueling Systems” with the Proposed text in order to align with IFC. This change will allow repair garages to have similar designs across the country, while maintaining the same level of safety. The IFC text also provides additional guidance on procedures, closed transfer systems, vent pipe design, and venting operation.

The edits in red represent changes from IFC or from the existing text. 18.7.4.3 modifies the vent pipe requirements to point to Section 6 and 7 instead of CGA 5.5 which significantly limits the location of the defueling pipe. The text in 18.7.4.9 and 18.7.4.10 has been mis-interpreted by AHJs to apply to the vehicle. The proposed changes modifies the IFC text to clarify that the venting only applies to the defueling system and not the vehicle. The additional sentence in 18.7.4.7 allows for defueling from a tank mounted in a vehicle





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18.7.3 Manufacturer Specific Equipment Required.

Equipment supplied by the vehicle manufacturer shall be used to connect the vehicle The defueling equipment that connects the vehicle fuel supplycontainers to be defueled to the defueling system shall be specifically designed for the vehicle it is connecting to . Defueling equipment provided by thevehicle manufacture is recommended.


The PI provides the option for the use of defueling equipment not provided by the manufacturer, while still stating the equipment should be designed for that specific vehicle. It also encourages the repair garage to use manufacturer equipment. Flexibility is needed to allow for different equipment suppliers





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Vent Pipe Termination

18.7.5.1 The vent exit elevation shall be a minimum of 10 ft (3 m) above grade; or 2 ft (0.61 m) above adjacent equipment; or 5 ft (1.5 m) aboverooftops.18.7.5.2 The exits of vent stacks shall be located so the concentration of vented gas at any point of personnel exposure is below the flammable orasphyxiation limit. Exits of vent stacks shall be located outdoors and away from personnel areas, ignition sources, air intakes, building openings,and overhangs.





Related

A.6.16 The termination point for piped vent systems serving cylinders, containers, tanks, and gas systems used for the purpose of operational or emergency venting [should] be located to prevent impingement exposure on the system served and to minimize the effects of high temperature thermal radiation or the effects of contact with the gas from the escaping plume to the supply system, personnel, adjacent structures, and ignition sources. [55:6.15]


7.1.17.3.1 Venting of [GH2] shall be directed to an approved location. [55:7.3.1.5.1]

7.1.17.3.2 The termination point for piped vent systems serving cylinders, containers, tanks, and gas systems used for the purpose of operational or emergency venting shall be in accordance with Section 6.16. [55:7.3.1.5.2]

18.3 General.

18.3.1 Motor Vehicle Repair Areas. Repairing of motor vehicles shall be restricted to areas specifically provided for such purposes. [30A:9.7.1]

18.3.1.1 The discharge or defueling of hydrogen from fuel supply containers shall be required for the purpose of fuel storage system modification or repair or when welding or open flame activities occur within 18 in. (0.45 m) of the vehicle fuel supply container. Defueling shall be in accordance with Section 18.7.

18.3.1.2 Other than for those repairs listed in 18.3.1.1, repairs that would be required to be performed in a major repair garage shall be permitted to be performed in a minor repair garage if the vehicle is defueled in accordance with Section 18.7 to less than 200 scf (5.7 Nm3) and the fuel supply container is sealed.


18.7.1 Methods of Discharge. The discharge of hydrogen from motor vehicle fuel storage tanks shall be accomplished through an approved method of atmospheric venting in accordance with 18.7.1 through 18.7.6.

18.7.2 Defueling Equipment Required at Vehicle Maintenance and Repair Facilities. Major repair garages shall have equipment to defuel vehicle fuel supply containers. Equipment used for defueling shall be listed and labeled for the intended use.

18.7.3 Manufacturer Equipment Required. Equipment supplied by the vehicle manufacturer shall be used to connect the vehicle fuel supply containers to be defueled to the defueling system.

18.7.4 Isolated Use. The defueling shall not be connected to another venting system used for any other purpose.

SourceCGA G5.5-2014

6.2.4 Discharge of warm gasHigh exit velocities in a vertically released vent and the low density of warm, gaseous hydrogen in relation to air will aid in its dispersion and dilution in the atmosphere. The vent exit elevation should be the greater of the elevation determined in 6.2.3 or 10 ft (3 m) above grade; or 2 ft (0.61 m) above adjacent equipment; or 5 ft (1.5 m) above rooftops.

6.2.8 Vent locationsThe exits of vent stacks shall be located so the concentration of vented gas at any point of personnel exposure is below the flammable or asphyxiation limit. Exits of vent stacks shall be located outdoors and away from personnel areas, ignition sources, air intakes, building openings, and overhangs. The siting distances from exposures specified in NFPA 55. required by the authority having jurisdiction (AHJ) or local fire code requirements, as applicable, can be used as general guidelines to locate vent stacks for hydrogen user locations [4].




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Public Input No. 341-NFPA 2-2016 [New Section after 6.16] Same topic/need

Public Input No. 343-NFPA 2-2016 [Chapter A [Excluding any Sub-Sections]]





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The defueling system shall:

(1) include a method of grounding and bonding

and operator instructions to facilitate safe use. The defueling nozzle of

(1) .

(2) be bonded with the vehicle storage tank system

shall be bonded with the defueling system

(1) prior to the commencement of discharge or defueling operations.

(2) include operator instructions to facilitate proper use.


Three requirements, three clear line item instructions.




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add new chapter 19 “ Mobile Hydrogen Fuel Systems “

Add new NFPA 2 chapter to cover mobile applications by third party converter companies including all cases where H35 and H70 hydrogenvehicle fuel systems (CHSS) are used for such applications as portable fuel delivery systems, portable energy or lighting system, smallquantity electric utility vehicles such as garbage trucks, street sweepers, airport service vehicles, mobile hydrogen dispenser test systems.

APPROACH: Create a new chapter in NFPA 2 with requirements for medium duty, heavy duty and off-road hydrogen powered vehicles andutility systems…with H2 specific requirements and capturing relevant requirements from two chapters from NFPA 52 (2016) :

· NFPA-52: Chapter 14 Automotive Equipment (Onboard)

· NFPA-52: Chapter 15 Automotive Fuel and Safety Systems (Onboard)

Copyright 2016 National Fire Protection Association (NFPA). NFPA-52 VEHICULAR NATURAL GAS FUEL SYSTEMS CODE 2016 Edition

Note: This is a placeholder text that will need to be further developed before inclusion in NFPA 2

19.1 Scope

19.1.1 This chapter shall apply to equipment that uses Compressed hydrogen storage systems (CHSS) for hydrogen fuel source for mobileapplications such as portable power or lighting system s , delivery truck APUs, and small production quantiles of medium and heavy duty FuelCell electric drive utility vehicles such as garbage trucks, FEDEX or UPS trucks, street sweepers, airport service vehicles .

19.1.2 Mobile, portable or transportable systems that have a CHSS and use an SAE J-2600 fuel receptacle interface shall comply with the pressure classrequirements in 19.2.3

19.2 General Requirements

19.2.1 All components that contact hydrogen shall be designed for the temperature and pressure range for the service conditions expected during fuelingand mobile operations.

19.2.2 The high pressure fuel system components that are part of the Compressed Hydrogen Storage System (CHSS) shall be rated for hydrogen serviceat temperatures from -40 C to 100 C and for a maximum operating pressure of 1.25 x service pressure

19.2.3 components of the Compressed Hydrogen Storage system (CHSS) shall be rated for service temperature from -40 C to 85 C and shall be cycletested at 1.5 x service pressure.

19.2.4 The installation, testing, maintenance and repair of all vehicle fuel systems and mobile devices with CHSS storage system shall be in accordancewith chapter 19

19.2.5 Modifications. Modifications of a vehicle gaseous fuel system shall conform with, when available, the engineering recommendations of the originalspecifications of the original chassis vehicle manufacturer. (52:15.2.1)

19.3.6 The system integrator shall obtain, when available, documented approval of the chassis original equipment and component manufacturers of theonboard fuel and detection systems components, and verify proper installation and application for each of the following: (52:15.2.3.1)

(1) Vehicle

(2) Chassis

(3) Engine

(4) Gas detection

(5) Fuel system

19.3.7 Modifications of a vehicle gaseous fuel system shall conform with, when available, the engineering recommendations of the original specifications ofthe original chassis vehicle manufacturer. (52:15.2.3.2)

19.3.8 Integration. The system integrator shall be responsible for integration of the engine, fuel system, and gaseous detection system, where required,onto the vehicle chassis and for the operation of the vehicle. (52:15.2.4)

19.3 Pressure Class

The service pressure classes for hydrogen mobile system are H25, H35, H50 and H70 , Table define the pressure limitations of hydrogendispenser and vehicle fuel systems as shown in table 19.3

PressureClass

ServicePressure

(SP)

MaximumVehicle

FillPressure

(1.25 xSP)

MaximumAllowableDispenser

HosePressure

Relief ValveSet-Point

(1.375 x SP)

VehicleTank

SystemProof

Pressure

(1.5 x SP)

H25 25 31.25 34.375 37.5

H35 35 43.75 48.125 52.5

H50 50 62.5 68.75 75

H70 70 87.5 96.25 105

Table 19.3

19.3.1 all component of the vehicle tank system (CHSS) shall be tested at a proof pressure of 1.5 x service pressure

19.4 Isolation of hydrogen

19.4.1 Mobile fuel systems that supply fuel to vehicle sub-systems while underway shall include an in-tank valve with ability to isolate high pressurehydrogen within all storage tubes in the event of an emergency, loss of containment or vehicle crash


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19.4.2 Portable or mobile hydrogen storage systems that do not utilize an automatic in-tank valve shall have a manual in-tank valve that shall be closed fortransport

19.4.3 Portable or mobile hydrogen storage systems that have external valves shall be closed during transit and designed to protect connected externalvalves in a vehicle crash.

19.3.4 Every fuel container on shall be equipped with a normally closed, remotely actuated shutoff valve connected directly to the container

10.3.5 Vehicles with more than one fuel supply container, where each container is equipped with a normally closed remotely actuated shutoff valve, shallhave an automatic system to detect the failure of any one of the valves. (52:15.3.3.6.1.2)

19.3.6 When shut-off valves are attached directly to fuel containers, there shall be a means for the technician to determine if there is still pressure in thecontainer, regardless of the valve position. (52:15.3.3.6.1.3)

19.3.7 A means shall be provided to bleed the container manually even in the event that a remote actuated shutoff valve fails or an excess flow deviceshould remain closed. (52:15.3.3.6.1.5)

19.3.8 Fuel System Isolation. In addition to the automatic shutoff valve required for each storage cylinder, a manual shutoff valve or a normally closed,automatically actuated shutoff valve shall be installed that allows isolation of the low pressure fuel supply system

(A) An additional manual shutoff valve shall not be required on vehicles that are not normally operated on public streets, that have a single fuel supplycontainer, and that are equipped with an accessible manual container shutoff valve.

(B) The fuel system isolation valve shall be mounted and shielded or installed in a protected location to minimize damage from vibration and unsecuredobjects.

(C) Where a manual shutoff valve is used, it shall be in an accessible location.

(D) The manual shutoff valve shall have not more than 90 degrees rotation (quarter turn fuel delivery valve) from the open to the closed positions.

(E) Access to the manual shutoff valves shall not require the use of any key or tool.

(F) Where a manual shutoff valve is used, the valve location shall be indicated by means of a decal or label containing the words “MANUAL SHUTOFFVALVE.”

(G) A weather-resistant decal or label with red, blue, or black letters on a white or silver reflective background shall be used.

19.5 fill connection system

19.5.1 CNG CH2 vehicle fueling connection devices shall be listed in accordance with ANSI/IAS NGV1 SAE J-2600 , Standard for CompressedNatural Gas Hydrogen Vehicle ( H N GV) Fueling Connection Devices. (52:14.4.2.7.1)

19.5.2 The service pressure of the fueling connection receptacle shall not exceed the service pressure of the fuel supply cylinders. (52:14.4.2.7.3.2)

19.5.3 A ll components in the high pressure fuel circuit shall be proof tested to 1.5 x service pressure in accordance with table 14.4.1.1(52:14.4.2.7.3.2)

19.5.3.1 Fueling connections installed on vehicles less than 10,000 lb (4500 kg) gross vehicle weight rating (GVWR) shall be in accordance with SAEJ-2600 for use on light duty vehicles

19.5.3.2 Larger vehicles such as buses and trucks shall be permitted to use fueling connections that are designed to prevent the connection of a lowerservice pressure vehicle to a higher service pressure source. (52:15.3.3.7.2)

19.5.4 The fueling connection receptacle shall be mounted to withstand the breakaway force specified in 8.4.2.4. (52:15.3.3.7.3)

19.5.5 The receptacle shall be installed in accordance with the manufacturer’s instructions. (52:15.3.3.7.4)

19.5.6 The clearance around the fueling connection shall be free of interference that prevents the connection of the fueling nozzle. (52:15.3.3.7.5)

19.6 Fuel Backflow Prevention.

19.6.1 The fueling system shall be equipped with a backflow check valve that prevents the return flow of gas from the container(s) to the fillingconnection.

19.6.2 One backflow check valve shall be mounted directly to each tank valve

19.6.3 A primary check valve shall be located at the fueling receptacle

19.5 High pressure fueling circuit

19.5.1 Pipe, tubing, fittings, gaskets, and packing material shall be compatible with hydrogen under the maximum service conditions. (52:14.4.2.5.2)

19.5.2 Pipe, tubing, fittings, and other components shall be designed with a minimum safety factor of 3. (52:14.4.2.5.3)

19.5.3 Natural gas Hydrogen piping shall be fabricated and tested in accordance with ANSI/ASME B31.3, Process Piping. (52:14.4.2.5.4)

19.5.4 Piping components such as filters, snubbers, and expansion joints shall be permanently marked by the manufacturer to indicate the service ratings.(52:14.4.2.5.7)

19.5.5 Valves, valve packing, and gaskets shall be designed or selected for the fuel over the full range of pressures and temperatures to which they aresubjected under operating conditions. (52:14.4.2.6.1)

19.5.6 Shutoff valves for vehicles shall have a service pressure not less than the service pressure of the fuel container and shall be capable ofwithstanding a hydrostatic test of at least four times the operating pressure (1.25 times the service pressure)

19.5.7 Leakage shall not occur at less than 1.5 times the rated operating pressure. (52:14.4.2.6.1.3)

19.5.8 Valves of a design that allows the valve stem to be removed without removal of the complete valve bonnet or without disassembly of the valve bodyshall not be used. (52:14.4.2.6.2)

19.5.8.1 The manufacturer shall stamp or otherwise permanently mark the valve body to indicate the service ratings. (52:14.4.2.6.3)

19.5.10 Hose and metallic hose shall be constructed of materials that are resistant to corrosion from the environmental and exposure to natural gashydrogen under operational range of conditions. (52:14.4.2.8.1)

19.5.10.1 Prior to use, hose assemblies shall be tested by the system integrator OEM or its designated representative at a pressure of at least 1.5 xservice pressure (52:14.4.2.8.2.1)

19.5.10.2 Vehicle hose, metallic hose, flexible metal hose, tubing, and their connections shall be designed or selected for the most severe pressures andtemperatures under normal operating conditions with a burst pressure of at least four times the operating pressure. (52:14.4.2.8.3)

19.5.10.3 Hose and metallic hose shall be distinctly marked by the OEM or component manufacturer, either by the manufacturer's permanently attachedtag or by distinct markings indicating the manufacturer's name or trademark, applicable service identifier, and design pressure. (52:14.4.2.8.4)

19.5.10.4 Vehicle hoses, metallic hose, flexible metal hose, tubing, and their connections shall comply with the requirements in 14.4.2.8 or ANSI NGV 3.1.(52:14.4.2.8.5)

19.5.11 Manifolds connecting fuel containers shall be fabricated and installed to minimize vibration. (52:15.2.8.1)


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19.5.11.1 Manifolds shall be installed in a protected location or shielded to prevent damage from unsecured objects. (52:15.2.8.1.1)

19.5.11.2 Manifolds connecting containers or container pressure relief devices shall be designed to vent gas from the individual container(s) exposed to afire meet the requirements of Section

19.5.11.3 Manifolds connecting fuel containers shall be fabricated and installed to minimize vibration. (52:15.2.8.1)

19.5.11.4 Manifolds shall be installed in a protected location or shielded to prevent damage from unsecured objects. (52:15.2.8.1.1)

19.5.11.5 Manifolds connecting containers or container pressure relief devices shall be designed to vent gas from the individual container(s) exposed to afire meet the requirements of Section 14.4.2.2. (52:15.2.8.2)

19.5.12 Valves shall be mounted securely and shielded or installed in a protected location to prevent damage from vibration, shock, and unsecured objects.(52:15.2.9.1)

19.5.13Valves shall be installed so that their weight is not placed on, or supported by, the attached lines. (52:15.2.9.2)

19.8 Hydrogen Storage

19.8.1 Cylinders shall be manufactured in accordance with both of the following: (52:14.4.2.1.5.1)

(1) ANSI NGV HGV 2, Compressed Natural Gas Hydrogen Vehicle ( H N GV) Fuel Containers, specifically for CNG CH2 service

( 2) U.S. Federal Motor Vehicle Safety Standard, 49 CFR 571.304, Compressed Natural Gas Hydrogen Fuel Container Integrity

19.8.2 Cylinders that have reached the labeled expiration date shall be removed from service. . (52:14.2.1.5.2)

19.9 Installation of Fuel Supply Containers.

19.9.1 Locations of Fuel Supply Containers. Fuel supply containers on vehicles shall be permitted to be located within,

below, or above the driver or passenger compartment, provided all connections to the container(s) are external to, or sealed and vented from, thesecompartments. (52:15.2.6.1)

19.9.2 Containers shall be installed and fitted so that no gas from fueling operations can be released inside the passenger compartment, by permanentlyinstalling the fueling receptacle outside the passenger compartment of the vehicle in a location protected from physical damage and dislodgment.(52:15.2.6.2)

19.9.3 Installation of Containers. Fuel supply containers shall be installed in accordance with the instructions of the container manufacturer and the fuelspecific requirements in for CNG CH2

19.9.3.1 Containers shall be mounted to prevent their jarring loose, slipping, or rotating. (52:15.2.6.4.1)

19.9.3.2 Containers shall be secured to the vehicle body, bed, or frame by means capable of withstanding the loads defined in the figure below (NFPA-52:15.3.3.1.6)

19.10 PRDs

19.10.1 Each cylinder in the CHSS shall be fitted with one or more thermally activated pressure relief devices (PRDs) with the number, location, and partnumber as specified by the cylinder manufacturer and shall be marked and certified in accordance with ANSI/CSA PRD 1, Pressure Relief Devices forNatural Gas Hydrogen Vehicle ( NGV HGV ) Fuel Containers.

19.10.2 Containers shall be permitted to be protected using a combination of fire-resistant barriers and PRDs. (52:14.4.2.2.1)

19.10.3 The discharge flow rate of the PRD shall not be reduced below that required for the capacity of the container upon which the device is installed.(52:14.4.2.2.1.1)

19.11 Installation of PRD Systems.

15.3.3.8.1 All PRDs shall be in direct communication with the fuel. (52:15.3.3.8.1)

15.3.3.8.2 PRD manifolds connecting two or more containers shall be permitted if in accordance with the container manufacturer’s instructions.(52:15.3.3.8.2)

15.3.3.8.3 The PRD for the protection of the container shall be installed in the same vehicle compartment as the container. (52:15.3.3.8.3)

19.12 PRD Venting.

19.12.1 The discharge from the PRD shall be vented to the outside of the vehicle. (52:15.3.3.8.4.1)

19.12.2 Vent tube or hose shall be electrically conductive. (52:15.3.3.8.4.2)

19.12.2 Vent tube or hose shall be secured at intervals in such a manner as to minimize the possibility of damage, corrosion, or breakage of either thevent line or the pressure relief device due to expansion, contraction, vibration, strains, or wear and to preclude any loosening while in operation.(52:15.3.3.8.4.3)

19.12.3 Vent tube or hose shall have a burst pressure of at least 1.5 times the pressure in the vent that results from activation of the PRD. (52:15.3.3.8.4.4)

19.12.4 Vent(s) shall not discharge: (52:15.3.3.8.4.5)

(1) Into or toward the passenger or luggage compartment

(2) Into or toward wheel wells

(3) Toward CNG CH2 storage systems

(4) Toward the front of the vehicle

(5) Toward exhaust systems

(6) Into an engine compartment

19.12.5 Vent opening(s) shall not restrict the operation of a container pressure relief device or pressure relief device channel. (52:15.3.3.8.7)


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19.12.5.1 Means shall be provided to prevent water, dirt, insects, and any foreign objects from collecting in the vent lines or pressure relief devices.(52:15.3.3.9.1)

19.12.5.2 Protective devices in 19.12.5.1 shall not restrict the flow of gas. (52:15.3.3.9.2)

19.13 Vent Location and Signage.

19.13.1 For vehicles with GVWR in excess of 19,500 lb (8863 kg), the following shall apply:

(1) Vent outlets shall be located vertically near the top of the vehicle.

(2) Vent outlets shall be orientated to direct the vent gas upward.

19.13.2 A safety sign(s) as depicted in Figure 19.13.2.3 shall indicate the PRD vent location. (52:15.3.3.10.1)

19.13.2.1 Each safety sign shall be 3 in. tall by 5 in. wide and shall use 18 point san serif font for the message text. (52:15.3.3.10.2)

19.13.2.2 One safety sign shall be located near each vent area. (52:15.3.3.10.3)

WARNING

CNG CH2 Vent Hazard

During vehicle fire: Keep people away

Prepare for large flame and let fire burn

Gas vents here

Failure to comply may injure or kill.

FIGURE 19.13.2.3

19.14 System Testing

19.14.1 * The completed fuel system assembly shall be leak tested using natural gas hydrogen or inert gas. (52:15.3.8.1)

19.14.2 Before use, every connection not previously tested in subassemblies shall be inspected for leaks with a noncorrosive leak detector solution or aleak detector instrument after the equipment is connected and pressurized to its service pressure. Passing inspection shall require the following:(52:15.3.8.2)

(1) Each connection shall have no bubbles in three minutes.

(2) Any leakage as noted in 19.14.2 (1) shall be corrected; and

(3) The system shall be leak-checked again after any corrections, modifications, disassembly, repairs or replacement of components of the natural gashydrogen system.

19.15 System Inspection, Maintenance, and Repair.

19.15.1 Damaged fuel lines shall be replaced and not repaired. (52:15.3.9.1)

19.15.2 All containers, container appurtenances, piping systems, venting systems, and other components shall be maintained in accordance with themanufacturer's requirements. (52:15.3.9.2)

19.15.3 Vehicle supply containers shall be inspected in accordance with the schedule in the vehicle label required in 15.3.6 and one of the following:(52:15.3.9.3)

(1) Vehicle manufacturer’s instructions

(2) Container manufacturer’s instructions

(3) The instructions in CGA C-6.4, Methods for External Visual Inspection of Natural Gas Vehicle (NGV) and Hydrogen Vehicle ((HGV) Fuel Containers andTheir Installations. Personnel inspecting vehicle fuel supply containers shall be trained on CGA C-6.4.

19.15.4 Fuel containers whose service life has expired shall be removed from service. (52:15.3.9.3.1)

19.15.5 After periodic container inspection, a label showing the next required inspection date shall be affixed as required in 15.3.6.1. (52:15.3.9.3.2)

19.15.6 Pressure relief devices on fuel containers shall be maintained in accordance with the following: (52:15.3.9.4)

(1) Pressure relief device channels or other parts that interfere with the functioning of the device shall not be plugged by paint or accumulation of dirt.

(2) Only qualified personnel shall be permitted to service pressure relief devices.

(3) No pressure relief valve that has been in service shall be repaired or reworked without the written authorization of the pressure relief devicemanufacturer, valve manufacturer, fuel container manufacturer, or vehicle manufacturer. Any device that has been activated shall not be reworked or reusedand shall be removed from service.

(4) No pressure relief device that has been in service shall be reinstalled on another fuel cylinder.

19.15.7 The following shall be done during vehicle maintenance: (52:15.3.9.5)

(1) Ensure the engine is isolated from the fuel supply unless engine operation is required. If a manual isolation valve is used, it shall comply with 15.3.3.6.2.

(2) Prohibit torches, welding, or grinding equipment on or near high-pressure fuel lines and containers.

(3) Prevent damage to containers, including actions such as dropping, dragging, or rolling of the container.

(4) Prevent exposure of containers to strong chemicals such as battery acid or metal-cleaning solvents.

(5) Store CNG CH2 containers in a manner to avoid damage.

(6) Protect stored containers from sunlight.

(7) Containers shall be stored in accordance with manufacturers’ instructions.

(8) The openings in all stored cylinders shall be closed to prevent the entry of moisture and other contaminants.

(9) Reinstall containers to their original configuration using approved gaskets, bolts, nuts, washers, and parts in accordance with the recommendations ofthe vehicle or container manufacturer or system installer.

(10) Prevent hoists or jacks from coming into direct contact with containers.

(11) Prohibit personnel from walking on containers unless permitted by the container manufacturer.

19.15.8 The system integrator OEMs, FSVIMs, alterers, and converters shall make available instructions for system maintenance and repair.(52:15.3.9.6)

19.16 Low pressure hydrogen piping

19.16.1 An automatic pressure-reducing regulator(s) shall be installed to reduce the fuel container pressure to a level consistent with the working pressurerequired by fuel cell system


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19.16.2 Means shall be provided to prevent regulator malfunctions due to refrigeration effects. (52:15.3.3.4.2)

19.16.3 Pressure Regulators.

19.16.3.1 Regulators shall be installed so that their weight is not placed on, or supported by, the attached gas lines. (52:15.3.3.4.3)

19.16.3.2 A pressure regulator inlet and each chamber shall be designed for its operating pressure with a pressure safety factor of at least four times theoperating pressure of the dispensing station.

19.16.3.3 Low-pressure chambers shall provide for overpressure relief or be able to withstand the service pressure of the upstream pressure chamber.(52:14.4.2.4.1)

19.16. 4 Metallic tubing and fittings shall be clear and free from cutting or threading burrs and scales. (52:15.3.3.5.2)

19.16.5 The ends of all metallic tubing shall be deburred or prepared in accordance with the fitting manufacturer’s recommendations. (52:15.3.3.5.2.1)

19.16.6 Where necessary to prevent abrasion, fuel lines passing through a panel shall be protected by grommets or other protective devices.(52:15.3.3.5.3)

19.16.7 Hydrogen fuel lines shall be protected the fuel lines from excessive heat by durable and effective means.

19.16.8 Fuel lines shall be mounted, braced, and supported to minimize vibration. (52:15.3.3.5.5)

19.16.9 Fuel lines shall be protected against damage, corrosion, or breakage due to strain or wear. (52:15.3.3.5.5.1)

19.16.10 A bend in metallic tubing shall be prohibited where such a bend weakens the tubing. (52:15.3.3.5.6)

19.16.11 Mechanical joints on fuel line systems shall be located in an accessible location and shall not be located where natural gas hydrogen leakagecan accumulate undetected. (52:15.3.3.5.7)

19.17 Depressurization of Vehicle Containers.

19.17.1 The venting or depressurization of a CNG CH2 container shall be performed only by trained personnel using written procedures in a repairgarage that meets the requirements of chapter 18 and the defueling requirements in 18.7

19.17.2 The gas to be removed from the container shall be discharged into a closed transfer system or vented by an approved method of atmosphericventing. (52:15.3.4.1.1)

19.17. 3 A valve shall be used to control the discharge of gas from high-pressure systems to a venting system. (52:15.3.4.1.2)

19.17.4 Personnel training container depressurization shall do the following: (52:15.3.4.2)

(1) Depressurize containers only in accordance with manufacturer’s instructions

(2) Use grounding to prevent static electrical charge buildup

(3) Limit the rate of gas release from plastic-lined containers to a value not greater than that specified by the container manufacturer

(4) Restrain containers during depressurization to prevent container movement

19.17.5 Direct gas venting shall be done through a vent tube that diverts the gas flow to atmosphere. (52:15.3.4.3)

19.17.5 The vent tube shall have a gastight connection to the container prior to venting. (52:15.3.4.3.1)

19.17.6 All components of the vent tube shall be grounded. (52:15.3.4.3.2)

19.18 Container Inspections.

19.18.1 Where a vehicle is involved in an accident or fire causing damage to the CNG CH2 container, or if the container is subjected to a pressuregreater than 125 percent of service pressure, the CNG CH2 container shall be replaced, inspected, or retested in accordance with the vehicle orcontainer manufacturer’s instructions.

19.18.2 The mechanic performing the replacement, removal, inspection, and/or retesting shall prepare a document certifying that the cylinder is acceptablefor return to service and present the document to be retained by the vehicle owner/operator and a copy to be retained by himself. The

document shall identify the vehicle, (by license plate number or vehicle identification number) and the cylinder (by serial number); describe the work doneand the dates of work; and provide the mechanic’s name and contact information. (52:15.3.5.1)

19.18.3 Where a vehicle is involved in an accident or fire causing damage to any part of the CNG CH2 fuel system, the system shall be repaired andretested (see Section 15.3.8) before being returned to service. The mechanic performing the repair and retesting shall prepare a document certifying thatthe CNG CH2 fuel system is acceptable for return to service and present the document to be retained by the vehicle’s owner/operator and a copy to beretained by himself. The document shall identify the vehicle (by license number or vehicle identification number) parts of the CNG CH2 fuel systemworked on; describe the work done and dates of work; and provide the mechanic’s name and contact information. (52:15.3.5.2)

19.18.4 Where a CNG CH2 container is removed from a vehicle to be installed within a different vehicle, it shall be inspected or retested in accordancewith the vehicle or container manufacturer’s inspection or requalification procedures before it is reinstalled. (52:15.3.5.3)

19.19 Labeling.

19.19.1 A vehicle equipped with a CNG CH2 fuel system shall bear the following permanent labels: (52:15.3.6.1)

(1) A label(s) readily visible and located in the engine compartment shall include the following:

(a) Identification as a CNG CH2 -fueled vehicle

(b) System designed and installed in conformance with NFPA 52-XXXX (insert the edition year of the code)

(c) Service pressure

(d) Installer/converter’s name or company and contact information (i.e., address, telephone number, and email)

(2) A label(s) located at the primary fueling connection receptacle shall include the following:


(b) System service pressure

(c) Fuel container life expiration (insert date for limited-life fuel containers. This label item is not required for containers with unlimited life.)

(d) “Fuel containers are to be inspected by (insert date) and each (insert number) months thereafter.”

(3) Label(s) located at each auxiliary fueling connection receptacle shall include the following:


(b) Service pressure

19.19.2 The fuel container inspection dates shall be changed after each required container inspection to denote the next required inspection date. (SeeSection 15.3.9 for inspections). (52:15.3.6.1.1)

19.19.3 In addition to the label(s) required by 15.3.6.1, each vehicle shall be identified with a permanent, diamond-shaped label located on the exteriorvertical surface or near-vertical surface on the lower right rear of the vehicle other than on the bumper of the vehicle. (52:15.3.6.2)


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19.19.4 The labels for vehicles less than 19,500 lb (8863 kg) GVWR shall be a minimum of 4.72 in. long °¡ 3.27 in. high (120 mm long °¡ 83 mm high).(52:15.3.6.2.1)

19.19.5 The labels for vehicles with a GVWR of 19,500 lb (8863 kg) or greater shall be a minimum of 5.7 in. long °¡ 4.2 in. high (145 mm long °¡ 107 mmhigh). (52:15.3.6.2.2)

19.19.6 The marking in the label required by 15.2.11.1.1 shall consist of a border and the letters “ CNG CH2 ” [1 in. (25 mm) minimum height centered inthe diamond] of silver or white reflective luminous material on a blue background. (52:15.3.6.2.3)

19.19.7 The marking in the label required by 15.2.11.1.2 shall consist of a border and the letters “ CNG CH2 ” [1.2 in. (30 mm) minimum height centeredin the diamond] in silver or white reflective luminous material on a blue background. In addition to placement of the “ CNG CH2 ” diamond label on theright rear of the vehicle, the “ CNG CH2 ” diamond label shall also be affixed to both sides of the power unit.

19.19.8 Vehicles with roof-mounted CNG CH2 fuel containers shall include a permanent label in the driver's compartment, clearly visible to a seatedoperator, which includes the maximum total height of the unladen vehicle. (52:15.3.6.2.5)

19.19.9 Each assembly of CNG CH2 containers shall be permanently labeled near the container valve as follows: DANGER. Venting of the pressurefrom this system requires the use of special instructions or tools that can be obtained from the manufacturer [Insert the name, telephone number, and emailaddress of the vehicle manufacturer or system installer]. (52:15.3.6.3)

19.19.20 Each CNG CH2 or LNG each vehicle shall be identified with a permanent, diamond-shaped label located on the exterior vertical surface ornear-vertical surface on the lower right rear of the vehicle other than on the bumper of the vehicle (or on the trunk lid of a vehicle so equipped, but not on thebumper or tailgate of any vehicle), inboard from any other markings. (52:15.2.11.1)

19.19.20.1 The labels for vehicles less than 19,500 lb(8863 kg) GVWR shall be a minimum of 4.72 in. long °¡ 3.27 in. high (120 mm °¡ 83 mm).(52:15.2.11.1.1)

19.19.20.2 The labels for vehicles with a GVWR of 19,500 lb (8863 kg) or greater shall be a minimum of 5.7 in. long °¡ 4.2 in. high (145 mm °¡ 107 mm).(52:15.2.11.1.2)

19.19.20.3 The marking in the label required by 15.2.11.1.1 shall consist of a border and the letters “ CNG CH2 ” or “LNG,” as appropriate [1 in. (25mm) minimum height centered in the diamond] of silver or white reflective luminous material on a blue background. (52:15.2.11.1.3)

19.19.20.4 The marking in the label required in 15.2.11.1.2 shall consist of a border and the letters “ CNG CH2 ” or “LNG, ” as appropriate [1.2 in.(30 mm) minimum height centered in the diamond] of silver or white reflective luminous material on a blue background. (52:15.2.11.1.4)

19.19.20.5 The labels for 19,500 lb (8863 kg) GVWR and greater shall be a minimum of 5.7 in. long °¡ 4.2 in. high (145 mm °¡ 107 mm). In addition to therequirement in 15.2.11.1.2 for placement of the diamond-shaped label on the lower right rear of the vehicle, labels shall be affixed to each side of the powerunit. If a DOT number is required to be displayed in accordance with 49 CFR 390.21, then the labels shall be affixed near the DOT numbers on each side ofthe power unit. (52:15.2.11.1.5)

19.19.21 Vehicles with roof-mounted CNG CH2 fuel containers shall include a permanent label in the drive’s compartment, clearly visible to a seatedoperator, which includes the maximum total height of the unladen vehicle. (52:15.2.11.1.6)

19.20 Qualified Mechanic.

19.20.1 All personnel engaged in activities in 15.3.4, 15.3.8, and 15.3.9, namely, discharging CNG CH2 fuel containers or maintenance, repair,replacement, removal, and testing of CNG CH2 fuel system or its components shall be qualified mechanics with hydrogen vehicle safety training.



new_NFPA_2_Chapter_19_-_Mobile_Hydrogen_Fuel_Systems_160629_.docx

this is a word file with extracts from NFPA-52 (2016) chapters 14 and 15 modified for H2 mobile systems


The need for these requirements is quite urgent as there are no established standards for mobile hydrogen systems and yet we are having systems in the built environment being fueled today as portable power supplies, and other systems.

There is a California infrastructure requirement that the only authorization to fuel is a credit card.

DOE has a high priority for the development of the market for medium and heavy duty vehicles as well as transportable auxiliary power units




Street Address:

City:

State:

Zip:



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new NFPA 2 Chapter 19 “ Mobile Hydrogen Fuel Systems “

NFPA 2

Public Input Template Proposed Changes: new chapter 19 “ Mobile Hydrogen Fuel Systems “

Add new NFPA 2 chapter to cover mobile applications by third party converter companies

including all cases where H35 and H70 hydrogen vehicle fuel systems (CHSS) are used for such

applications as portable fuel delivery systems, portable energy or lighting system, small quantity

electric utility vehicles such as garbage trucks, street sweepers, airport service vehicles, mobile

hydrogen dispenser test systems.

APPROACH: Create a new chapter in NFPA 2 with requirements for medium duty, heavy duty

and off-road hydrogen powered vehicles and utility systems…with H2 specific requirements and

capturing relevant requirements from two chapters from NFPA 52 (2016) :

NFPA-52: Chapter 14 Automotive Equipment (Onboard)

NFPA-52: Chapter 15 Automotive Fuel and Safety Systems (Onboard)

Copyright 2016 National Fire Protection Association (NFPA). NFPA-52 VEHICULAR NATURAL GAS FUEL SYSTEMS CODE 2016 Edition

This is a placeholder text and will need to be further developed before inclusion in NFPA 2

Existing Text: not applicable

Substantiation Statement: the need for this current as there are no established standards and

yet we are having systems in the built environment being fueled today as portable power

supplies, and other systems. There is a California infrastructure requirement that the only

authorization to fuel is a credit card. DOE has a high priority for the development of the

market for medium and heavy duty vehicles as well as transportable auxiliary power units

Editorial notes

Revision Author Notes

5/30/16 160530

Bob Boyd

First proposal, to get the ball rolling with a capture from NFPA-52 2016 CNG vehicle tank installation requirements. On the following pages are the relevant sections of the chapters 14 and 15 in NFPA-52 with the LNG specific language removed for clarity and with CNG changed to CH2. The word copy was made with track changes active for all changes important to show traceability to the original code from NFPA 52

6/12/16 160612

Bob Boyd

The initial proposal (PI) and concept was shared with members of the FCHEA codes and standards working group and the concept was discussed with experts at the AMR this past week. This copy incorporates feedback and is an update on the first proposal. The table of contents was added and some NFPA-52 text was reformatted to aid in the editorial process.

6/29/16 Bob Boyd

Corrected dates of first and second revisions. Started on process of new chapter development, editing of old chapter. This is just a beginning of needed technical and editorial process and presented for further work as a placeholder

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2

Public Input Template ............................................................................................................................. 1

Review of the Contents of NFPA 52 chapter 14 and 15 language ............................................................. 5

Proposed New Chapter Content .............................................................................................................. 6

19.1 Scope ......................................................................................................................................... 6

19.2 General Requirements ................................................................................................................ 6

19.3 Pressure Class ............................................................................................................................ 7

19.4 Isolation of hydrogen ................................................................................................................... 7

19.5 fill connection system .................................................................................................................. 8

19.6 Fuel Backflow Prevention. ............................................................................................................ 9

19.5 High pressure fueling circuit ......................................................................................................... 9

19.8 Hydrogen Storage ..................................................................................................................... 11

19.9 Installation of Fuel Supply Containers. ..................................................................................... 11

19.10 PRDs ........................................................................................................................................ 12

19.11 Installation of PRD Systems. .................................................................................................. 12

19.12 PRD Venting. ......................................................................................................................... 12

19.13 Vent Location and Signage. ..................................................................................................... 13

19.14 System Testing ...................................................................................................................... 14

19.15 System Inspection, Maintenance, and Repair ......................................................................... 14

19.16 low pressure hydrogen piping ................................................................................................ 15

19.17 Depressurization of Vehicle Containers. ................................................................................ 16

19.18 Container Inspections. ............................................................................................................ 16

19.19 Labeling. ................................................................................................................................. 17

19.19 Qualified Mechanic. ................................................................................................................. 19

Text from NFPA-52 that was not brought into NFPA-2 Chapter 19 ......................................................... 19

15.3.3.7 Installation of Fueling Connectors. ....................................................................................... 20

15.3.3.11 Gastight Enclosures. ........................................................................................................... 20

15.3.3.6.4* Multiple Fuel Systems. .................................................................................................... 20

14.4.2 System Component Qualifications. ............................................................................................. 20

14.4.2.3 Pressure Gauges. .................................................................................................................. 20

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3

14.4.2.5 Piping, Tubing, and Fittings. ................................................................................................. 21

14.4.2.6 Valves. ................................................................................................................................. 21

Chapter 15 Automotive Fuel and Safety Systems (Onboard) .............................................................. 23

15.2.5 System Component Qualifications. .......................................................................................... 23

15.2.7 Installation of Venting Systems. .............................................................................................. 24

15.2.8 Installation of Fuel Lines. ......................................................................................................... 24

15.2.9 Installation of Valves. .............................................................................................................. 24

15.2.10.3 Wiring Installation. ............................................................................................................. 24

15.3 CH2 Engine Fuel Systems. .......................................................................................................... 24

15.3.3.3 Installation of Pressure Gauges. ........................................................................................... 24

XXXXXX---------- Original Text from NFPA-52--------XXXXX ....................................................................... 26

14.1Scope. ......................................................................................................................................... 26

14.4.2 System Component Qualifications. ............................................................................................. 26

14.4.2.1.5* Cylinders. ........................................................................................................................ 27

14.4.2.2 Pressure Relief Devices (PRDs). See Annex C. ....................................................................... 27

14.4.2.3 Pressure Gauges. .................................................................................................................. 27

14.4.2.4 Pressure Regulators. ............................................................................................................ 27

14.4.2.5 Piping, Tubing, and Fittings. ................................................................................................. 28

14.4.2.6 Valves. ................................................................................................................................. 28

14.4.2.7 Vehicle Fueling Connection. ................................................................................................. 28

14.4.2.8 Hose and Hose Connections. ................................................................................................ 29

Chapter 15 Automotive Fuel and Safety Systems (Onboard) .............................................................. 30

15.2.5 System Component Qualifications. .......................................................................................... 31

15.2.6 Installation of Fuel Supply Containers...................................................................................... 31

15.2.6.4 Securing Containers. ............................................................................................................ 31

15.2.7 Installation of Venting Systems. .............................................................................................. 31

15.2.8 Installation of Fuel Lines. ......................................................................................................... 31

15.2.9 Installation of Valves. .............................................................................................................. 31

15.2.10.3 Wiring Installation. ............................................................................................................. 32

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4

15.2.11 Labeling. ............................................................................................................................... 32

15.3 CH2 Engine Fuel Systems. .......................................................................................................... 32

15.3.3 Installation of Fuel Supply Containers...................................................................................... 32

FIGURE 15.3.3.1.6 The Six Principal Directions. .................................................................................. 33

15.3.3.3 Installation of Pressure Gauges. ........................................................................................... 33

15.3.3.4 Installation of Pressure Regulators. ...................................................................................... 34

15.3.3.6 Fuel-Subsystem Isolation. ..................................................................................................... 34

15.3.3.6.4* Multiple Fuel Systems. .................................................................................................... 35

15.3.3.6.5 Fuel Backflow Prevention. ................................................................................................. 35

15.3.3.7 Installation of Fueling Connectors. ....................................................................................... 35

15.3.3.8* Installation of PRD Systems. ............................................................................................... 35

15.3.3.10* Vent Location and Signage. .............................................................................................. 35

15.3.3.11 Gastight Enclosures. ........................................................................................................... 36

15.3.4 Discharge from Vehicle Containers. ......................................................................................... 36

15.3.5 Container Inspections. ............................................................................................................ 36

15.3.6 Labeling. ................................................................................................................................. 36

15.3.8 System Testing. ....................................................................................................................... 37

15.3.9.7 Qualified Mechanic. ............................................................................................................. 38

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5

Review of the Contents of NFPA 52 chapter 14 and 15 language

This is an ongoing effort to track the changes.

NFPA 52 section

NFPA 52 language NFPA-2 Section

New chapter 19 in NFPA 2

Chapter 14 Automotive Equipment (Onboard) 19 Mobile Hydrogen Fuel Systems

14.1 Scope 19.1 Scope

14.2 Application

14.3 General

14.4 CNG (supplemental Requirements) 19.4 High Pressure Components

19.4.2 Pressure Class: H35, H70,

14.4.2 Design and construction of containers Need to clean this section up 14.4.2.1.5* Cylinders.

Need to review annex note

14.4.2.1.6 ASME Compliance. All references to ASME pressure vessels are not applicable to vehicle fuel tank systems and have been deleted from proposed lanaguage

14.4.2.2 Pressure Relief Devices (PRDs Need to look at NFPA 52 Annex C 14.4.2.6 Valves. 14.4.2.6.1.1 Shutoff valves for dispensing stations This does not belong in vehicle fuel systems 14.4.2.7 Vehicle Fueling Connection. Point to SAE J-2600

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Proposed New Chapter Content

19.1 Scope

19.1.1 This chapter shall apply to equipment that uses CNGCompressed and LNG fuel supply

(CHSS) for hydrogen fuel source for mobile applications such as portable power or lighting

systems, delivery truck APUs, and small production quantiles of medium and heavy duty Fuel

Cell electric drive utility vehicles such as garbage trucks, FEDEX or UPS trucks, street

sweepers, airport service vehicles.

19.1.2 Mobile, portable or transportable systems that have a CHSS and use an SAE J-2600 fuel

receptacle interface shall comply with the pressure class requirements in 19.2.3

19.2 General Requirements

19.2.1 All components that contact hydrogen shall be designed for the temperature and

pressure range for the service conditions expected during fueling and mobile operations.

19.2.2 The high pressure fuel system components that are part of the Compressed Hydrogen

Storage System (CHSS) shall be rated for hydrogen service at temperatures from -40 C to 100 C

and for a maximum operating pressure of 1.25 x service pressure

19.2.3 components of the Compressed Hydrogen Storage system (CHSS) shall be rated for

service temperature from -40 C to 85 C and shall be cycle tested at 1.5 x service pressure.

19.2.4 The installation, testing, maintenance and repair of all vehicle fuel systems and mobile

devices with CHSS storage system shall be in accordance with chapter 19

19.2.5 Modifications. Modifications of a vehicle gaseous fuel system shall conform with, when

available, the engineering recommendations of the original specifications of the original chassis

vehicle manufacturer. (52:15.2.1)

19.3.6 The system integrator shall obtain, when available, documented approval of the chassis

original equipment and component manufacturers of the onboard fuel and detection systems

components, and verify proper installation and application for each of the following:

(52:15.2.3.1)

(1) Vehicle

(2) Chassis

(3) Engine

(4) Gas detection

(5) Fuel system

19.3.7 Modifications of a vehicle gaseous fuel system shall conform with, when available, the

engineering recommendations of the original specifications of the original chassis vehicle

manufacturer. (52:15.2.3.2)

19.3.8 Integration. The system integrator shall be responsible for integration of the engine, fuel

system, and gaseous detection system, where required, onto the vehicle chassis and for the

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operation of the vehicle. (52:15.2.4)

19.3 Pressure Class

The service pressure classes for hydrogen mobile system are H25, H35, H50 and H70, Table

define the pressure limitations of hydrogen dispenser and vehicle fuel systems as shown in table

19.3

Pressure

Class

Service

Pressure

(SP)

Maximum

Vehicle Fill

Pressure

(1.25 x SP)

Maximum Allowable

Dispenser Hose

Pressure Relief Valve

Set-Point

(1.375 x SP)

Vehicle Tank

System Proof

Pressure

(1.5 x SP)

H25 25 31.25 34.375 37.5

H35 35 43.75 48.125 52.5

H50 50 62.5 68.75 75

H70 70 87.5 96.25 105

Table 19.3

19.3.1 all component of the vehicle tank system (CHSS) shall be tested at a proof pressure of

1.5 x service pressure

19.4 Isolation of hydrogen

19.4.1 Mobile fuel systems that supply fuel to vehicle sub-systems while underway shall

include an in-tank valve with ability to isolate high pressure hydrogen within all storage tubes in

the event of an emergency, loss of containment or vehicle crash

19.4.2 Portable or mobile hydrogen storage systems that do not utilize an automatic in-tank

valve shall have a manual in-tank valve that shall be closed for transport

19.4.3 Portable or mobile hydrogen storage systems that have external valves shall be closed

during transit and designed to protect connected external valves in a vehicle crash.

19.3.4 Every fuel container on shall be equipped with a normally closed, remotely actuated

shutoff valve connected directly to the container

10.3.5 Vehicles with more than one fuel supply container, where each container is equipped

with a normally closed remotely actuated shutoff valve, shall have an automatic system to detect

the failure of any one of the valves. (52:15.3.3.6.1.2)

19.3.6 When shut-off valves are attached directly to fuel containers, there shall be a means for

the technician to determine if there is still pressure in the container, regardless of the valve

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position. (52:15.3.3.6.1.3)

19.3.7 A means shall be provided to bleed the container manually even in the event that a

remote actuated shutoff valve fails or an excess flow device should remain closed.

(52:15.3.3.6.1.5)

19.3.8 Fuel System Isolation. In addition to the automatic shutoff valve required for each storage

cylinder, a manual shutoff valve or a normally closed, automatically actuated shutoff valve shall

be installed that allows isolation of the low pressure fuel supply system

(A) An additional manual shutoff valve shall not be required on vehicles that are not normally

operated on public streets, that have a single fuel supply container, and that are equipped with an

accessible manual container shutoff valve.

(B) The fuel system isolation valve shall be mounted and shielded or installed in a protected

location to minimize damage from vibration and unsecured objects.


(D) The manual shutoff valve shall have not more than 90 degrees rotation (quarter turn fuel

delivery valve) from the open to the closed positions.


(F) Where a manual shutoff valve is used, the valve location shall be indicated by means of a

decal or label containing the words “MANUAL SHUTOFF VALVE.”

(G) A weather-resistant decal or label with red, blue, or black letters on a white or silver

reflective background shall be used.

19.5 fill connection system

19.5.1 CNGCH2 vehicle fueling connection devices shall be listed in accordance with

ANSI/IAS NGV1SAE J-2600, Standard for Compressed Natural GasHydrogen Vehicle (HNGV)

Fueling Connection Devices. (52:14.4.2.7.1)

14.4.2.7.2 The refueling connection shall be permitted to be

19.5.3 All components in the high pressure fuel circuit shall be proof tested to 1.5 x service

pressure in accordance with table 14.4.1.1 (52:14.4.2.7.3.2)

19.5.3.1 Fueling connections installed on vehicles less than 10,000 lb (4500 kg) gross vehicle

weight rating (GVWR) shall be in accordance with SAE J-2600 for use on light duty vehicles

19.5.3.2 Larger vehicles such as buses and trucks shall be permitted to use fueling

connections that are designed to prevent the connection of a lower service pressure vehicle to a

higher service pressure source. (52:15.3.3.7.2)

19.5.4 The fueling connection receptacle shall be mounted to withstand the breakaway force

specified in 8.4.2.4. (52:15.3.3.7.3)

19.5.5 The receptacle shall be installed in accordance with the manufacturer’s instructions.

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(52:15.3.3.7.4)

19.5.6 The clearance around the fueling connection shall be free of interference that prevents

the connection of the fueling nozzle. (52:15.3.3.7.5)

19.6 Fuel Backflow Prevention.

19.6.1 The fueling system shall be equipped with a backflow check valve that prevents the

return flow of gas from the container(s) to the filling connection.

19.6.2 One backflow check valve shall be mounted directly to each tank valve

19.6.3 A primary check valve shall be located at the fueling receptacle

19.5 High pressure fueling circuit

19.5.1 Pipe, tubing, fittings, gaskets, and packing material shall be compatible with hydrogen

under the maximum service conditions. (52:14.4.2.5.2)

19.5.2 Pipe, tubing, fittings, and other components shall be designed with a minimum safety

factor of 3. (52:14.4.2.5.3)

19.5.3 Natural gasHydrogen piping shall be fabricated and tested in accordance with

ANSI/ASME B31.3, Process Piping. (52:14.4.2.5.4)


19.5.5 Valves, valve packing, and gaskets shall be designed or selected for the fuel over the full

range of pressures and temperatures to which they are subjected under operating conditions.

(52:14.4.2.6.1)

14.4.2.6.1.1 Shutoff valves for dispensing stations shall have a

19.5.7 Leakage shall not occur at less than 1.5 times the rated operating pressure.

(52:14.4.2.6.1.3)

19.5.8 Valves of a design that allows the valve stem to be removed without removal of the

complete valve bonnet or without disassembly of the valve body shall not be used.

(52:14.4.2.6.2)

19.5.8.1 The manufacturer shall stamp or otherwise permanently mark the valve body to

indicate the service ratings. (52:14.4.2.6.3)

19.5.10 Hose and metallic hose shall be constructed of materials that are resistant to corrosion

from the environmental and exposure to natural gashydrogen under operational range of

conditions. (52:14.4.2.8.1)

19.5.10.1 Prior to use, hose assemblies shall be tested by the system integrator OEM or its

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designated representative at a pressure of at least 1.5 x service pressure (52:14.4.2.8.2.1)

19.5.10.2 Vehicle hose, metallic hose, flexible metal hose, tubing, and their connections shall be

designed or selected for the most severe pressures and temperatures under normal operating

conditions with a burst pressure of at least four times the operating pressure. (52:14.4.2.8.3)

19.5.10.3 Hose and metallic hose shall be distinctly marked by the OEM or component

manufacturer, either by the manufacturer's permanently attached tag or by distinct markings

indicating the manufacturer's name or trademark, applicable service identifier, and design

pressure. (52:14.4.2.8.4)

19.5.10.4 Vehicle hoses, metallic hose, flexible metal hose, tubing, and their connections shall

comply with the requirements in 14.4.2.8 or ANSI NGV 3.1. (52:14.4.2.8.5)

19.5.11 Manifolds connecting fuel containers shall be fabricated and installed to minimize

vibration. (52:15.2.8.1)

19.5.11.1 Manifolds shall be installed in a protected location or shielded to prevent damage from

unsecured objects. (52:15.2.8.1.1)

19.5.11.2 Manifolds connecting containers or container pressure relief devices shall be designed

to vent gas from the individual container(s) exposed to a fire meet the requirements of Section

19.5.11.3 Manifolds connecting fuel containers shall be fabricated and installed to minimize

vibration. (52:15.2.8.1)

19.5.11.4 Manifolds shall be installed in a protected location or shielded to prevent damage from

unsecured objects. (52:15.2.8.1.1)

19.5.11.5 Manifolds connecting containers or container pressure relief devices shall be designed

to vent gas from the individual container(s) exposed to a fire meet the requirements of Section

14.4.2.2. (52:15.2.8.2)

19.5.12 Valves shall be mounted securely and shielded or installed in a protected location to

prevent damage from vibration, shock, and unsecured objects. (52:15.2.9.1)

19.5.13Valves shall be installed so that their weight is not placed on, or supported by, the

attached lines. (52:15.2.9.2)

19.8 Hydrogen Storage

19.8.1 Cylinders shall be manufactured in accordance with both of the following:

(52:14.4.2.1.5.1)

(1) ANSI NGV HGV 2, Compressed Natural GasHydrogen Vehicle (HNGV) Fuel

Containers, specifically for CNGCH2 service

(2) U.S. Federal Motor Vehicle Safety Standard, 49 CFR 571.304, Compressed Natural

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GasHydrogen Fuel Container Integrity

19.8.2 Cylinders that have reached the labeled expiration date shall be removed from service..

(52:14.2.1.5.2)

19.9 Installation of Fuel Supply Containers.

19.9.1 Locations of Fuel Supply Containers. Fuel supply containers on vehicles shall be

permitted to be located within,

below, or above the driver or passenger compartment, provided all connections to the

container(s) are external to, or sealed and vented from, these compartments. (52:15.2.6.1)

19.9.2 Containers shall be installed and fitted so that no gas from fueling operations can be

released inside the passenger compartment, by permanently installing the fueling receptacle

outside the passenger compartment of the vehicle in a location protected from physical damage

and dislodgment. (52:15.2.6.2)

19.9.3 Installation of Containers. Fuel supply containers shall be installed in accordance with

the instructions of the container manufacturer and the fuel specific requirements in for CNGCH2

19.9.3.1 Containers shall be mounted to prevent their jarring loose, slipping, or rotating.

(52:15.2.6.4.1)

19.9.3.2 Containers shall be secured to the vehicle body, bed, or frame by means capable of

withstanding the loads defined in the figure below (NFPA-52: 15.3.3.1.6)

19.10 PRDs

19.10.1 Each cylinder in the CHSS shall be fitted with one or more thermally activated pressure

Commented [BoydH21]: Need to revise this reference

Commented [BoydH22]: Need to verfy

Formatted: Font: (Default) Times New Roman, 9 pt, Font

color: Black

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relief devices (PRDs) with the number, location, and part number as specified by the cylinder

manufacturer and shall be marked and certified in accordance with ANSI/CSA PRD 1, Pressure

Relief Devices for Natural GasHydrogen Vehicle (NGVHGV) Fuel Containers.

19.10.2 Containers shall be permitted to be protected using a combination of fire-resistant

barriers and PRDs. (52:14.4.2.2.1)

19.10.3 The discharge flow rate of the PRD shall not be reduced below that required for the

capacity of the container upon which the device is installed. (52:14.4.2.2.1.1)

19.11 Installation of PRD Systems.

15.3.3.8.1 All PRDs shall be in direct communication with the fuel. (52:15.3.3.8.1)

15.3.3.8.2 PRD manifolds connecting two or more containers shall be permitted if in accordance

with the container manufacturer’s instructions. (52:15.3.3.8.2)

15.3.3.8.3 The PRD for the protection of the container shall be installed in the same vehicle

compartment as the container. (52:15.3.3.8.3)

19.12 PRD Venting.

19.12.1 The discharge from the PRD shall be vented to the outside of the vehicle.

(52:15.3.3.8.4.1)

19.12.2 Vent tube or hose shall be electrically conductive. (52:15.3.3.8.4.2)

19.12.2 Vent tube or hose shall be secured at intervals in such a manner as to minimize the

possibility of damage, corrosion, or breakage of either the vent line or the pressure relief device

due to expansion, contraction, vibration, strains, or wear and to preclude any loosening while in

operation. (52:15.3.3.8.4.3)

19.12.3 Vent tube or hose shall have a burst pressure of at least 1.5 times the pressure in the vent

that results from activation of the PRD. (52:15.3.3.8.4.4)

19.12.4 Vent(s) shall not discharge: (52:15.3.3.8.4.5)



(3) Toward CNGCH2 storage systems




19.12.5 Vent opening(s) shall not restrict the operation of a container pressure relief device or

pressure relief device channel. (52:15.3.3.8.7)

19.12.5.1 Means shall be provided to prevent water, dirt, insects, and any foreign objects from

collecting in the vent lines or pressure relief devices. (52:15.3.3.9.1)

19.12.5.2 Protective devices in 19.12.5.1 shall not restrict the flow of gas. (52:15.3.3.9.2)

Commented [BoydH23]: Need to verify

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19.13 Vent Location and Signage.

19.13.1 For vehicles with GVWR in excess of 19,500 lb (8863 kg), the following shall apply:



19.13.2 A safety sign(s) as depicted in Figure 19.13.2.3 shall indicate the PRD vent location.

(52:15.3.3.10.1)

19.13.2.1 Each safety sign shall be 3 in. tall by 5 in. wide and shall use 18 point san serif font for

the message text. (52:15.3.3.10.2)

19.13.2.2 One safety sign shall be located near each vent area. (52:15.3.3.10.3)

WARNING

CNGCH2 Vent Hazard

During vehicle fire: Keep people away

Prepare for large flame and let fire burn

Gas vents here

Failure to comply may injure or kill.

FIGURE 19.13.2.3

19.14 System Testing

19.14.1 * The completed fuel system assembly shall be leak tested using natural gashydrogen or

inert gas. (52:15.3.8.1)

19.14.2 Before use, every connection not previously tested in subassemblies shall be inspected

for leaks with a noncorrosive leak detector solution or a leak detector instrument after the

equipment is connected and pressurized to its service pressure. Passing inspection shall require

the following: (52:15.3.8.2)


(2) Any leakage as noted in 19.14.2 (1) shall be corrected; and

(3) The system shall be leak-checked again after any corrections, modifications, disassembly,

repairs or replacement of components of the natural gashydrogen system.

19.15 System Inspection, Maintenance, and Repair.

19.15.1 Damaged fuel lines shall be replaced and not repaired. (52:15.3.9.1)

19.15.2 All containers, container appurtenances, piping systems, venting systems, and other

components shall be maintained in accordance with the manufacturer's requirements.

(52:15.3.9.2)

19.15.3 Vehicle supply containers shall be inspected in accordance with the schedule in the

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vehicle label required in 15.3.6 and one of the following: (52:15.3.9.3)



(3) The instructions in CGA C-6.4, Methods for External Visual Inspection of Natural Gas

Vehicle (NGV) and Hydrogen Vehicle ((HGV) Fuel Containers and Their Installations.

Personnel inspecting vehicle fuel supply containers shall be trained on CGA C-6.4.

19.15.4 Fuel containers whose service life has expired shall be removed from service.

(52:15.3.9.3.1)

19.15.5 After periodic container inspection, a label showing the next required inspection date

shall be affixed as required in 15.3.6.1. (52:15.3.9.3.2)

19.15.6 Pressure relief devices on fuel containers shall be maintained in accordance with the

following: (52:15.3.9.4)

(1) Pressure relief device channels or other parts that interfere with the functioning of the device

shall not be plugged by paint or accumulation of dirt.


(3) No pressure relief valve that has been in service shall be repaired or reworked without the

written authorization of the pressure relief device manufacturer, valve manufacturer, fuel

container manufacturer, or vehicle manufacturer. Any device that has been activated shall not be

reworked or reused and shall be removed from service.


19.15.7 The following shall be done during vehicle maintenance: (52:15.3.9.5)

(1) Ensure the engine is isolated from the fuel supply unless engine operation is required. If a

manual isolation valve is used, it shall comply with 15.3.3.6.2.

(2) Prohibit torches, welding, or grinding equipment on or near high-pressure fuel lines and

containers.

(3) Prevent damage to containers, including actions such as dropping, dragging, or rolling of the

container.

(4) Prevent exposure of containers to strong chemicals such as battery acid or metal-cleaning

solvents.

(5) Store CNGCH2 containers in a manner to avoid damage.



(8) The openings in all stored cylinders shall be closed to prevent the entry of moisture and other

contaminants.

(9) Reinstall containers to their original configuration using approved gaskets, bolts, nuts,

washers, and parts in accordance with the recommendations of the vehicle or container

manufacturer or system installer.


(11) Prohibit personnel from walking on containers unless permitted by the container

manufacturer.

19.15.8 The system integrator OEMs, FSVIMs, alterers, and converters shall make available

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instructions for system maintenance and repair. (52:15.3.9.6)

19.16 Low pressure hydrogen piping

19.16.1 An automatic pressure-reducing regulator(s) shall be installed to reduce the fuel

container pressure to a level consistent with the working pressure required by fuel cell system

19.16.2 Means shall be provided to prevent regulator malfunctions due to refrigeration effects.

(52:15.3.3.4.2)

19.16.3 Pressure Regulators.

19.16.3.1 Regulators shall be installed so that their weight is not placed on, or supported by, the

attached gas lines. (52:15.3.3.4.3)

19.16.3.2 A pressure regulator inlet and each chamber shall be designed for its operating pressure with

a pressure safety factor of at least four times the operating pressure of the dispensing station.

19.16.3.3 Low-pressure chambers shall provide for overpressure relief or be able to withstand the

service pressure of the upstream pressure chamber. (52:14.4.2.4.1)

19.16. 4 Metallic tubing and fittings shall be clear and free from cutting or threading burrs and

scales. (52:15.3.3.5.2)

19.16.5 The ends of all metallic tubing shall be deburred or prepared in accordance with the

fitting manufacturer’s recommendations. (52:15.3.3.5.2.1)

19.16.6 Where necessary to prevent abrasion, fuel lines passing through a panel shall be

protected by grommets or other protective devices. (52:15.3.3.5.3)

19.16.7 Hydrogen fuel lines shall be protected the fuel lines from excessive heat by durable and

effective means.

19.16.8 Fuel lines shall be mounted, braced, and supported to minimize vibration.

(52:15.3.3.5.5)

19.16.9 Fuel lines shall be protected against damage, corrosion, or breakage due to strain or

wear. (52:15.3.3.5.5.1)

19.16.10 A bend in metallic tubing shall be prohibited where such a bend weakens the tubing.

(52:15.3.3.5.6)

19.16.11 Mechanical joints on fuel line systems shall be located in an accessible location and

shall not be located where natural gashydrogen leakage can accumulate undetected.

(52:15.3.3.5.7)

19.17 Depressurization of Vehicle Containers.

19.17.1 The venting or depressurization of a CNGCH2 container shall be performed only by

trained personnel using written procedures in a repair garage that meets the requirements of

chapter 18 and the defueling requirements in 18.7

19.17.2 The gas to be removed from the container shall be discharged into a closed transfer

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system or vented by an approved method of atmospheric venting. (52:15.3.4.1.1)

19.17. 3 A valve shall be used to control the discharge of gas from high-pressure systems to a

venting system. (52:15.3.4.1.2)

19.17.4 Personnel training container depressurization shall do the following: (52:15.3.4.2)



(3) Limit the rate of gas release from plastic-lined containers to a value not greater than that

specified by the container manufacturer


19.17.5 Direct gas venting shall be done through a vent tube that diverts the gas flow to

atmosphere. (52:15.3.4.3)

19.17.5 The vent tube shall have a gastight connection to the container prior to venting.

(52:15.3.4.3.1)

19.17.6 All components of the vent tube shall be grounded. (52:15.3.4.3.2)

19.18 Container Inspections.

19.18.1 Where a vehicle is involved in an accident or fire causing damage to the CNGCH2

container, or if the container is subjected to a pressure greater than 125 percent of service

pressure, the CNGCH2 container shall be replaced, inspected, or retested in accordance with the

vehicle or container manufacturer’s instructions.

19.18.2 The mechanic performing the replacement, removal, inspection, and/or retesting shall

prepare a document certifying that the cylinder is acceptable for return to service and present the

document to be retained by the vehicle owner/operator and a copy to be retained by himself. The

document shall identify the vehicle, (by license plate number or vehicle identification number)

and the cylinder (by serial number); describe the work done and the dates of work; and provide

the mechanic’s name and contact information. (52:15.3.5.1)

19.18.3 Where a vehicle is involved in an accident or fire causing damage to any part of the

CNGCH2 fuel system, the system shall be repaired and retested (see Section 15.3.8) before being

returned to service. The mechanic performing the repair and retesting shall prepare a document

certifying that the CNGCH2 fuel system is acceptable for return to service and present the

document to be retained by the vehicle’s owner/operator and a copy to be retained by himself.

The document shall identify the vehicle (by license number or vehicle identification number)

parts of the CNGCH2 fuel system worked on; describe the work done and dates of work; and

provide the mechanic’s name and contact information. (52:15.3.5.2)

19.18.4 Where a CNGCH2 container is removed from a vehicle to be installed within a

different vehicle, it shall be inspected or retested in accordance with the vehicle or container

manufacturer’s inspection or requalification procedures before it is reinstalled. (52:15.3.5.3)

19.19 Labeling.

19.19.1 A vehicle equipped with a CNGCH2 fuel system shall bear the following permanent

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labels: (52:15.3.6.1)


(a) Identification as a CNGCH2-fueled vehicle

(b) System designed and installed in conformance with NFPA 52-XXXX (insert the edition year

of the code)


(d) Installer/converter’s name or company and contact information (i.e., address, telephone

number, and email)




(c) Fuel container life expiration (insert date for limited-life fuel containers. This label item is not

required for containers with unlimited life.)

(d) “Fuel containers are to be inspected by (insert date) and each (insert number) months

thereafter.”




19.19.2 The fuel container inspection dates shall be changed after each required container

inspection to denote the next required inspection date. (See Section 15.3.9 for inspections).

(52:15.3.6.1.1)

19.19.3 In addition to the label(s) required by 15.3.6.1, each vehicle shall be identified with a

permanent, diamond-shaped label located on the exterior vertical surface or near-vertical surface

on the lower right rear of the vehicle other than on the bumper of the vehicle. (52:15.3.6.2)

19.19.4 The labels for vehicles less than 19,500 lb (8863 kg) GVWR shall be a minimum of

4.72 in. long °¡ 3.27 in. high (120 mm long °¡ 83 mm high). (52:15.3.6.2.1)

19.19.5 The labels for vehicles with a GVWR of 19,500 lb (8863 kg) or greater shall be a

minimum of 5.7 in. long °¡ 4.2 in. high (145 mm long °¡ 107 mm high). (52:15.3.6.2.2)

19.19.6 The marking in the label required by 15.2.11.1.1 shall consist of a border and the letters

“CNGCH2” [1 in. (25 mm) minimum height centered in the diamond] of silver or white

reflective luminous material on a blue background. (52:15.3.6.2.3)

19.19.7 The marking in the label required by 15.2.11.1.2 shall consist of a border and the letters

“CNGCH2” [1.2 in. (30 mm) minimum height centered in the diamond] in silver or white

reflective luminous material on a blue background. In addition to placement of the “CNGCH2”

diamond label on the right rear of the vehicle, the “CNGCH2” diamond label shall also be

affixed to both sides of the power unit.

19.19.8 Vehicles with roof-mounted CNGCH2 fuel containers shall include a permanent label

in the driver's compartment, clearly visible to a seated operator, which includes the maximum

total height of the unladen vehicle. (52:15.3.6.2.5)

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19.19.9 Each assembly of CNGCH2 containers shall be permanently labeled near the container

valve as follows: DANGER. Venting of the pressure from this system requires the use of special

instructions or tools that can be obtained from the manufacturer [Insert the name, telephone

number, and email address of the vehicle manufacturer or system installer]. (52:15.3.6.3)

19.19.20 Each CNGCH2 or LNG each vehicle shall be identified with a permanent, diamond-

shaped label located on the exterior vertical surface or near-vertical surface on the lower right

rear of the vehicle other than on the bumper of the vehicle (or on the trunk lid of a vehicle so

equipped, but not on the bumper or tailgate of any vehicle), inboard from any other markings.

(52:15.2.11.1)

19.19.20.1 The labels for vehicles less than 19,500 lb(8863 kg) GVWR shall be a minimum of

4.72 in. long °¡ 3.27 in. high (120 mm °¡ 83 mm). (52:15.2.11.1.1)

19.19.20.2 The labels for vehicles with a GVWR of 19,500 lb (8863 kg) or greater shall be a

minimum of 5.7 in. long °¡ 4.2 in. high (145 mm °¡ 107 mm). (52:15.2.11.1.2)

19.19.20.3 The marking in the label required by 15.2.11.1.1 shall consist of a border and the

letters “CNGCH2” or “LNG,” as appropriate [1 in. (25 mm) minimum height centered in the

diamond] of silver or white reflective luminous material on a blue background. (52:15.2.11.1.3)

19.19.20.4 The marking in the label required in 15.2.11.1.2 shall consist of a border and the

letters “CNGCH2” or “LNG, ” as

19.19.20.5 The labels for 19,500 lb (8863 kg) GVWR and greater shall be a minimum of 5.7 in.

long °¡ 4.2 in. high (145 mm °¡ 107 mm). In addition to the requirement in 15.2.11.1.2 for

placement of the diamond-shaped label on the lower right rear of the vehicle, labels shall be

affixed to each side of the power unit. If a DOT number is required to be

displayed in accordance with 49 CFR 390.21, then the labels shall be affixed near the DOT

numbers on each side of the power unit. (52:15.2.11.1.5)

19.19.21 Vehicles with roof-mounted CNGCH2 fuel containers shall include a permanent label

in the drive’s compartment, clearly visible to a seated operator, which includes the maximum

total height of the unladen vehicle. (52:15.2.11.1.6)

19.20 Qualified Mechanic.

19.20.1 All personnel engaged in activities in 15.3.4, 15.3.8, and 15.3.9, namely, discharging

CNGCH2 fuel containers or maintenance, repair, replacement, removal, and testing of CNGCH2

fuel system or its components shall be qualified mechanics with hydrogen vehicle safety training.

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Text from NFPA-52 that was not brought into NFPA-2 Chapter 19

14.2 Application. CNGCH2 P and LNG equipment used shall be in accordance with Section 14.3

and the fuel specific sections of

14.3 General. (52:14.3)

14.3.1 System Component Qualifications. (Reserved) (52:14.3.1)

14.3.2 System Approvals. (52:14.3.2)

14.3.2.1 OEM Approved Equipment. The following CNGCH2 and

(1) Vehicle fuel containers

(2) Fuel quantity gauging systems


(4) Pressure measurement devices


(6) Valves



(9) Vaporizers

(10) Pumps

(11) Electrical equipment related to engine fuel systemson-board fuel management


(13) Fire protection and suppression equipment

14.3.2.2 Safety Equivalent. Devices not otherwise specifically provided for shall be constructed

to provide safety equivalent

to that required for other parts of a system. (52:14.3.2.2)

14.3.3 Equipment. (52:14.3.3)

14.3.3.1 Pressure Gauges. A pressure gauge, if provided, shall be capable of reading at least 1.2

times the maximum allowable working pressure for the dispensing station or 1.2 °¡ 1.25 times

the service pressure for the vehicle. (52:14.3.3.1)

15.3.3.7 Installation of Fueling Connectors.

(7) Toward an emergency exit

15.3.3.8.5 The vent opening shall not be blocked by debris thrown up from the road, such as snow, ice, mud, and so on, or

otherwise affected by the elements. (52:15.3.3.8.5)

15.3.3.8.6 Vent opening(s) shall resist accumulation of water due to rain, vehicle washing, and moisture due to condensation.

(52:15.3.3.8.6)

15.3.3.11 Gastight Enclosures. 15.3.3.11.1 The neck of the container and all CNGCH2 fittings within the compartment shall be enclosed in a gastight enclosure

made of linear, low-density polyethylene having a minimum thickness of 8 mils (0.20 mm) or an equally gastight alternate

enclosure that is vented directly to the outside of the vehicle. (52:15.3.3.11.1)

15.3.3.11.2 The gastight enclosure shall not be constructed of fire-resistant material. (52:15.3.3.11.2)

15.3.3.6.4* Multiple Fuel Systems. Where multiple fuel systems are installed on the vehicle, automatic valves shall be provided, as necessary, to shut off the fuel not

being used.

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14.4.2 System Component Qualifications.

14.4.2.1* Design and Construction of Containers. (52:14.4.2.1)

14.4.2.1.1 Containers shall be fabricated of steel, aluminum,

14.4.2.1.2 The container shall be designed for CNGCH2 service. (52:14.4.2.1.2)

14.4.2.1.3 The container shall be permanently marked “CNGCH2”by the manufacturer.

(52:14.4.2.1.3)

14.4.2.1.4 Containers manufactured prior to the effective date of this code shall be permitted to

be used in CNGCH2 service if recommended for CNGCH2 service by the container

manufacturer or if approved by the authority having jurisdiction. (52:14.4.2.1.4)

14.4.2.3 Pressure Gauges.

A pressure gauge, if provided, shall be capable of reading at least 1.2 times the maximum

allowable

working pressure for the dispensing station or 1.2 °¡ 1.25 times the service pressure for the

vehicle.

14.4.2.5 Piping, Tubing, and Fittings.

14.4.2.5.1 The following components shall not be used for CNGCH2 service: (52:14.4.2.5.1)

(1) Fittings, street els, and other piping components of cast irons other than those complying with

ASTM A47, Standard

Specification for Ferritic Malleable Iron Castings (Grade 35018); ASTM A395, Standard

Specification for Ferritic

Ductile Iron Pressure-Retaining Castings for Use at Elevated Temperatures; and ASTM A536,

Standard Specification for

Ductile Iron Castings (Grade 60-40-18)

(2) Plastic pipe, tubing, and fittings for high-pressure service

(3) Galvanized pipe and fittings

(4) Aluminum pipe, tubing, and fittings

(5) Pipe nipples for the initial connection to a container

(6) Copper alloy with copper content exceeding 70 percent

14.4.2.6 Valves.

14.4.2.6.4 Valves of cast irons other than those complying with ASTM A47, Standard

Specification for Ferritic Malleable Iron Castings (Grade 35018); ASTM A395, Standard

Specification for Ferritic Ductile Iron Pressure-Retaining Castings for Use at Elevated

Temperatures; and ASTM A536, Standard Specification for Ductile Iron Castings (Grade 60-40-

18), shall not be used as primary stop valves.in hydrogen service (52:14.4.2.6.4)

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14.4.2.7.3.2 The service pressure of the fueling receptacle

Chapter 15 Automotive Fuel and Safety Systems (Onboard)

15.1 Application. This chapter shall apply to the design, installation, inspection, and testing of

CNGCH2 and LNG fuel

supply systems serving vehicle internal combustion engines. (52:15.1)

15.2.5 System Component Qualifications.

In addition to the requirements of 15.2.2, system components shall comply with the applicable

provisions of Chapter 8 and with 15.2.5.1 and15.2.5.2.

15.2.5.1 Fuel-carrying components, with the exception of container valves, tubing, and fittings,

shall be labeled or stamped with the following: (52:15.2.5.1)

(1) Manufacturer’s name or symbol

(2) Model designation

(3) Design service pressure or working pressure depending upon location in the vehicle

(4) Direction of fuel flow where necessary for correct installation

(5) Capacity or electrical rating, as applicable

15.2.5.2 All other components shall be designed or selected for service for a minimum

temperature range of –40°„F (–40°„C)

to 180°„F (82°„C).

and for LN

15.2.7 Installation of Venting Systems.

15.2.7.1 Enclosures, structures, seals, and conduits used to vent enclosures shall be fabricated of

materials designed to

resist damage, blockage, or dislodgment caused by the movement of articles carried in the

vehicle or by the closing of

luggage compartment enclosures or vehicle doors. (52:15.2.7.1)

15.2.7.1.1 Enclosures shall require the use of tools for removal. (52:15.2.7.1.1)

15.2.8 Installation of Fuel Lines.

15.2.9 Installation of Valves.

15.2.10.3 Wiring Installation.

15.2.10.3.1 Wiring shall be secured and protected from abrasion and corrosion to the same

standard as the original wiring on the vehicle. (52:15.2.10.3.1)

15.2.10.3.2 All wiring shall be sized according to the Society of Automotive Engineers (SAE)

and fuse-protected. (52:15.2.10.3.2)

15.3 CNGCH2 Engine Fuel Systems.

15.3.1 Scope. In addition to the general requirements of Section 15.2, the fuel specific

requirements of Section 15.3

apply to fuel systems serving CNGCH2 fueled vehicles. (52:15.3.1)

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15.3.1.1 Where there is a conflict between a general requirement and a fuel specific requirement,

the fuel specific requirement

shall apply. (52:15.3.1.1)

15.3.2 System Component Qualifications. (52:15.3.2)

15.3.2.1 In addition to the requirements of Section 15.2, system components shall comply with

the applicable provisions of Chapter 15 and this section. (52:15.3.2.1)

15.3.2.2 Devices not otherwise specifically provided for shall be constructed to provide safety

equivalent to that required for

other parts of a system. (52:15.3.2.2)

15.3.2.3 Temperature Range. Components in the engine compartment shall be designed or

selected for a minimum temperature range of −40°„F to 250°„F (−40°„C to 121°„C).

(52:15.3.2.3)

15.3.2.4 System components shall comply with the applicable provisions of Chapter 15 and this

section. (52:15.3.2.4

15.3.3.3 Installation of Pressure Gauges.

15.3.3.3.1 Pressure gauges located within a driver or passenger compartment shall be installed in

such a manner that no gas flows into the passenger compartment in the event of failure.

(52:15.3.3.3.1)

15.3.3.3.2 Pressure gauges installed outside a driver or passenger compartment shall be equipped

with a limiting orifice, a shatterproof lens, and a body relief. (52:15.3.3.3.2)

15.3.3.3.3 Pressure gauges shall be mounted, shielded, and installed in a protected location to

prevent damage from vibration

and unsecured objects. (52:15.3.3.3.3)

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XXXXXX---------- Original Text from NFPA-52--------XXXXX

This has been modified to capture NFPA-52 (2016) reference clause numbers at the end of each of the

requirements, and section headers have been added to allow for the use of the index at the beginning of

this word document

Chapter 1419 Mobile Hydrogen Fuel Systems Automotive Equipment (Onboard)

14.1Scope. This chapter shall apply to equipment used in CNGCompressed and LNG fuel supply systems serving vehicular

internal

New Annex Note: A.14.1 The requirements for light duty vehicle CHSS include the requirements in

SAE J-2579, GTR-xx and…

14.2 Application. CNGCH2 P and LNG equipment used shall be in accordance with Section 14.3 and the fuel specific sections of

14.3 General. (52:14.3)

14.3.1 System Component Qualifications. (Reserved) (52:14.3.1)

14.3.2 System Approvals. (52:14.3.2)

14.3.2.1 OEM Approved Equipment. The following CNGCH2 and

recommended by the original equipment manufacturer(OEM) for the intended service and shall be listed or

(1) Vehicle fuel containers

(2) Fuel quantity gauging systems


(4) Pressure measurement devices


(6) Valves



(9) Vaporizers

(10) Pumps

(11) Electrical equipment related to engine fuel systemson-board fuel management


(13) Fire protection and suppression equipment

14.3.2.2 Safety Equivalent. Devices not otherwise specifically provided for shall be constructed to provide safety equivalent

to that required for other parts of a system. (52:14.3.2.2)

14.3.3 Equipment. (52:14.3.3)

14.3.3.1 Pressure Gauges. A pressure gauge, if provided, shall be capable of reading at least 1.2 times the maximum allowable

working pressure for the dispensing station or 1.2 °¡ 1.25 times the service pressure for the vehicle. (52:14.3.3.1)

14.4 CNGHigh Pressure Components (52:14.4) (Supplemental Requirements).

14.4.1 Application. This section applies only to pressurized system components handling CNGCH2. (52:14.4.1)

14.4.2 System Component Qualifications. 14.4.2.1* Design and Construction of Containers. (52:14.4.2.1)

14.4.2.1.1 Containers shall be fabricated of steel, aluminum,

14.4.2.1.2 The container shall be designed for CNGCH2 service. (52:14.4.2.1.2)

14.4.2.1.3 The container shall be permanently marked “CNGCH2”by the manufacturer. (52:14.4.2.1.3)

14.4.2.1.4 Containers manufactured prior to the effective date of this code shall be permitted to be used in CNGCH2 service if

recommended for CNGCH2 service by the container manufacturer or if approved by the authority having jurisdiction.

(52:14.4.2.1.4)

14.4.2.1.5* Cylinders. 14.4.2.1.5.1 Cylinders shall be manufactured in accordance with both of the following: (52:14.4.2.1.5.1)

(1) ANSI NGV HGV 2, Compressed Natural GasHydrogen Vehicle (HNGV) Fuel Containers, specifically for CNGCH2 service

Formatted: Level 1

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(2) U.S. Federal Motor Vehicle Safety Standard, 49 CFR 571.304, Compressed Natural GasHydrogen Fuel Container Integrity

14.4.2.1.5.2 Cylinders that have reached the labeled expiration date shall be removed from service. Cylinders that are

disconnected, depressurized, and permanently disabled shall be permitted to be left on the vehicle. (52:14.2.1.5.2)

14.4.2.1.5.3* Composite reinforced cylinders or other cylinders marked with exemption or special permit numbers shall

be removed from service. (52:14.4.2.1.5.3)

14.4.2.1.6 ASME Compliance.

14.4.2.2 Pressure Relief Devices (PRDs). See Annex C. 14.4.2.2.1 Each cylinder complying with 14.4.2.1.4 shall be fitted with one or more thermally activated pressure relief devices

(PRDs) with the number, location, and part number as specified by the cylinder manufacturer and shall be marked

and certified in accordance with ANSI/CSA PRD 1, Pressure Relief Devices for Natural GasHydrogen Vehicle (NGVHGV) Fuel

Containers.

Containers shall be permitted to be protected using a combination of fire-resistant barriers and PRDs. (52:14.4.2.2.1)

14.4.2.2.1.1 The discharge flow rate of the PRD shall not be reduced below that required for the capacity of the container

upon which the device is installed. (52:14.4.2.2.1.1)

14.4.2.2.2 Pressure vessels complying with 14.4.2.1.5 used for stationary storage without temperature compensation of the

storage operating pressure shall be protected with one or more spring-loaded pressure relief valves in accordance with the

ASME Boiler and Pressure Vessel Code. (52:14.4.2.2.2)

14.4.2.2.2.1 The minimum rate of discharge of PRDs on containers shall be in accordance with CGA S-1.3, Pressure Relief

Device Standards — Part 3 — Stationary Storage Containers for Compressed Gases, or the ASME Boiler and Pressure Vessel

Code, whichever is applicable. (52:14.4.2.2.2.1)

14.4.2.2.2.2 Pressure relief valves (PRVs) for CNGCH2 service shall not be fitted with lifting devices. (52:14.4.2.2.2.2)

(A) The adjustment, if external, shall be provided with a

means for sealing the adjustment to prevent tampering.

(B) If at any time it is necessary to break such a seal, the valve shall be removed from service until it has been reset and

sealed.

(C) Adjustments shall be made only by the manufacturer or other companies having competent personnel and facilities for

the repair, adjustment, and testing of such valves.

(D) The organization making such adjustments shall attach a permanent tag with the setting, capacity, and date.

14.4.2.3 Pressure Gauges. A pressure gauge, if provided, shall be capable of reading at least 1.2 times the maximum allowable

working pressure for the dispensing station or 1.2 °¡ 1.25 times the service pressure for the vehicle.

14.4.2.4 Pressure Regulators. A pressure regulator inlet and each chamber shall be designed for its operating pressure with

a pressure safety factor of at least four times the operating pressure of the dispensing station.

14.4.2.4.1 Low-pressure chambers shall provide for overpressure relief or be able to withstand the service pressure of the

upstream pressure chamber. (52:14.4.2.4.1)

14.4.2.4.2 A vehicle pressure regulator shall comply with the requirements in 14.4.2.4 or ANSI NGV 3.1. (52:14.4.2.4.2)

14.4.2.5 Piping, Tubing, and Fittings. 14.4.2.5.1 The following components shall not be used for CNGCH2 service: (52:14.4.2.5.1)

(1) Fittings, street els, and other piping components of cast irons other than those complying with ASTM A47, Standard

Specification for Ferritic Malleable Iron Castings (Grade 35018); ASTM A395, Standard Specification for Ferritic

Ductile Iron Pressure-Retaining Castings for Use at Elevated Temperatures; and ASTM A536, Standard Specification for

Ductile Iron Castings (Grade 60-40-18)

(2) Plastic pipe, tubing, and fittings for high-pressure service

(3) Galvanized pipe and fittings

(4) Aluminum pipe, tubing, and fittings

(5) Pipe nipples for the initial connection to a container

(6) Copper alloy with copper content exceeding 70 percent

14.4.2.5.2 Pipe, tubing, fittings, gaskets, and packing material shall be compatible with the fuel under the maximum service

conditions. (52:14.4.2.5.2)

14.4.2.5.3 Pipe, tubing, fittings, and other components shall be designed with a minimum safety factor of 3. (52:14.4.2.5.3)

14.4.2.5.4 Natural gasHydrogen piping shall be fabricated and tested in accordance with ANSI/ASME B31.3, Process Piping.

(52:14.4.2.5.4)


to indicate the service ratings. (52:14.4.2.5.7)

Commented [BoydH24]: Need to revise this reference

Commented [BoydH25]: Need to verfy

Commented [BoydH26]: Need to verify

Formatted: Level 1

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14.4.2.6 Valves. 14.4.2.6.1 Valves, valve packing, and gaskets shall be designed or selected for the fuel over the full range of pressures and

temperatures to which they are subjected under operating conditions. (52:14.4.2.6.1)

14.4.2.6.1.1 Shutoff valves for dispensing stations shall have a

and shall be capable of withstanding a hydrostatic test of at least four times the operating pressure (1.25 times the service

pressure) or shall comply with the requirements in ANSI NGV 3.1. (52:14.4.2.6.1.2)

14.4.2.6.1.3 Leakage shall not occur at less than 1.5 times the rated operating pressure. (52:14.4.2.6.1.3)

14.4.2.6.2 Valves of a design that allows the valve stem to be removed without removal of the complete valve bonnet or without

disassembly of the valve body shall not be used. (52:14.4.2.6.2)

14.4.2.6.3 The manufacturer shall stamp or otherwise permanently mark the valve body to indicate the service ratings.

(52:14.4.2.6.3)

14.4.2.6.3.1 Container valves incorporating integral PRDs complying with 14.4.2.6.1 shall not require additional marking.

(52:14.4.2.6.3.1)

14.4.2.6.4 Valves of cast irons other than those complying with ASTM A47, Standard Specification for Ferritic Malleable Iron

Castings (Grade 35018); ASTM A395, Standard Specification for Ferritic Ductile Iron Pressure-Retaining Castings for Use at

Elevated Temperatures; and ASTM A536, Standard Specification for Ductile Iron Castings (Grade 60-40-18), shall not be used

as primary stop valves.in hydrogen service (52:14.4.2.6.4)

14.4.2.7 Vehicle Fueling Connection. 14.4.2.7.1 CNGCH2 vehicle fueling connection devices shall be listed in accordance with ANSI/IAS NGV1SAE J-2600,

Standard for Compressed Natural GasHydrogen Vehicle (HNGV) Fueling Connection Devices. (52:14.4.2.7.1)


14.4.2.7.3.1 The service pressure of the fueling connection receptacle shall not exceed the service pressure of the fuel

supply cylinders. (52:14.4.2.7.3.2)

14.4.2.7.3.2 All components in the high pressure fuel circuit shall be proof tested to 1.5 x service pressure in accordance with

table 14.4.1.1 (52:14.4.2.7.3.2)

14.4.2.7.3.2 The service pressure of the fueling receptacle 14.4.2.8.1 Hose and metallic hose shall be constructed of or lined with materials that are resistant to corrosion and exposure

to natural gashydrogen. (52:14.4.2.8.1)

14.4.2.8.2.1 Prior to use, hose assemblies shall be tested by the OEM or its designated representative at a pressure of at least

twice the maximum allowable working pressure (MAWP). (52:14.4.2.8.2.1)

14.4.2.8.3 Vehicle hose, metallic hose, flexible metal hose, tubing, and their connections shall be designed or selected for

the most severe pressures and temperatures under normal operating conditions with a burst pressure of at least four times

the operating pressure. (52:14.4.2.8.3)

14.4.2.8.3.1 Prior to use, hose assemblies shall be tested by the OEM or its designated representative at a pressure of at least

twice the operating pressure. (52:14.4.2.8.3.1)

14.4.2.8.4 Hose and metallic hose shall be distinctly marked by the OEM or component manufacturer, either by the

manufacturer's permanently attached tag or by distinct markings indicating the manufacturer's name or trademark, applicable

service identifier, and design pressure. (52:14.4.2.8.4)

14.4.2.8.5 Vehicle hoses, metallic hose, flexible metal hose, tubing, and their connections shall comply with the requirements in

14.4.2.8 or ANSI NGV 3.1. (52:14.4.2.8.5)

14.5 LNG Supplemental Requirements.

Chapter 15 Automotive Fuel and Safety Systems (Onboard) 15.1 Application. This chapter shall apply to the design, installation, inspection, and testing of CNGCH2 and LNG fuel

supply systems serving vehicle internal combustion engines. (52:15.1)

15.1.1 The installation, testing, maintenance and repair of gaseous vehicle fuel systems shall be in accordance with

Section 15.2 and the fuel specific requirements of Sections 15.3 or 15.4 as applicable. (52:15.1.1)

15.2 General. (52:15.2)

15.2.1 Modifications. Modifications of a vehicle gaseous fuel system shall conform with, when available, the engineering

recommendations of the original specifications of the original chassis vehicle manufacturer. (52:15.2.1)

15.2.2 OEM Approved Equipment. The subsystems and components if used, shall be meet the general and applicable

fuel specific equipment requirements of Chapter 15. (52:15.2.2)

15.2.3* Responsibilities of the OEM, Final-Stage Vehicle Integrator/Manufacturer, or Vehicle Alterer or Converter. (52:15.2.3)

15.2.3.1 All those listed in 15.2.3 shall obtain, when available, documented approval of the chassis original equipment and

component manufacturers of the onboard fuel and detection systems components, and verify proper installation and application

for each of the following: (52:15.2.3.1)

(1) Vehicle

(2) Chassis

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(3) Engine

(4) Gas detection

(5) Fuel system

15.2.3.2 Modifications of a vehicle gaseous fuel system shall conform with, when available, the engineering recommendations

of the original specifications of the original chassis vehicle manufacturer. (52:15.2.3.2)

15.2.4* Integration. All those listed in 15.2.3 shall be responsible for integration of the engine, fuel system, and gaseous

detection system, where required, onto the vehicle chassis and for the operation of the vehicle. (52:15.2.4)

15.2.5 System Component Qualifications. In addition to the requirements of 15.2.2, system components shall comply withthe applicable provisions of Chapter 8 and with

15.2.5.1 and15.2.5.2.

15.2.5.1 Fuel-carrying components, with the exception of container valves, tubing, and fittings, shall be labeled or stamped with

the following: (52:15.2.5.1)

(1) Manufacturer’s name or symbol

(2) Model designation

(3) Design service pressure or working pressure depending upon location in the vehicle

(4) Direction of fuel flow where necessary for correct installation

(5) Capacity or electrical rating, as applicable

15.2.5.2 All other components shall be designed or selected for service for a minimum temperature range of –40°„F (–40°„C)

to 180°„F (82°„C).

15.2.6 Installation of Fuel Supply Containers. 15.2.6.1 Locations of Fuel Supply Containers. Fuel supply containers on vehicles shall be permitted to be located within,

below, or above the driver or passenger compartment, provided all connections to the container(s) are external to, or sealed and

vented from, these compartments. (52:15.2.6.1)

15.2.6.2 Containers Mounted in the Interior of Vehicles.

Containers shall be installed and fitted so that no gas from fueling operations can be released inside the passenger compartment,

by permanently installing the fueling receptacle outside the passenger compartment of the vehicle in a location protected

from physical damage and dislodgment. (52:15.2.6.2)

15.2.6.3 Installation of Containers. Fuel supply containers shall be installed in accordance with the instructions of the container

manufacturer and the fuel specific requirements in for CNGCH2 (52:15.2.6.3)and for LNG.

15.2.6.4 Securing Containers. 15.2.6.4.1 Containers shall be mounted to prevent their jarring loose, slipping, or rotating. (52:15.2.6.4.1)

15.2.6.4.2 Containers shall be secured to the vehicle body, bed, or frame by means capable of withstanding the loads

defined in 15.4.4.2. (52:15.2.6.4.2)

15.2.7 Installation of Venting Systems. 15.2.7.1 Enclosures, structures, seals, and conduits used to vent enclosures shall be fabricated of materials designed to

resist damage, blockage, or dislodgment caused by the movement of articles carried in the vehicle or by the closing of

luggage compartment enclosures or vehicle doors. (52:15.2.7.1)

15.2.7.1.1 Enclosures shall require the use of tools for removal. (52:15.2.7.1.1)

15.2.8 Installation of Fuel Lines. 15.2.8.1 Manifolds connecting fuel containers shall be fabricated and installed to minimize vibration. (52:15.2.8.1)

15.2.8.1.1 Manifolds shall be installed in a protected location or shielded to prevent damage from unsecured objects.

(52:15.2.8.1.1)

15.2.8.2 Manifolds connecting containers or container pressure relief devices shall be designed to vent gas from the individual

container(s) exposed to a fire meet the requirements of Section 14.4.2.2. (52:15.2.8.2)

15.2.9 Installation of Valves. 15.2.9.1 Valves shall be mounted securely and shielded or installed in a protected location to prevent damage from vibration,

shock, and unsecured objects. (52:15.2.9.1)

15.2.9.2 Valves shall be installed so that their weight is not placed on, or supported by, the attached lines. (52:15.2.9.2)

15.2.10 Installation of Electrical Wiring. (52:15.2.10)

15.2.10.1 Wiring shall be installed, supported, and secured in a manner to prevent damage due to vibration, shock, strains, wear,

or corrosion. (52:15.2.10.1)

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15.2.10.2 All conductors shall be sized for the maximum anticipated load and shall be protected by overcurrent protection

devices. (52:15.2.10.2)

15.2.10.3 Wiring Installation. 15.2.10.3.1 Wiring shall be secured and protected from abrasion and corrosion to the same standard as the original wiring on the

vehicle. (52:15.2.10.3.1)

15.2.10.3.2 All wiring shall be sized according to the Society of Automotive Engineers (SAE) and fuse-protected.

(52:15.2.10.3.2)

15.2.11 Labeling. 15.2.11.1 Each CNGCH2 or LNG each vehicle shall be identified with a permanent, diamond-shaped label located on the exterior

vertical surface or near-vertical surface on the lower right rear of the vehicle other than on the bumper of the vehicle (or on the

trunk lid of a vehicle so equipped, but not on the bumper or tailgate of any vehicle), inboard from any other markings.

(52:15.2.11.1)

15.2.11.1.1 The labels for vehicles less than 19,500 lb(8863 kg) GVWR shall be a minimum of 4.72 in. long °¡ 3.27 in. high

(120 mm °¡ 83 mm). (52:15.2.11.1.1) 15.2.11.1.2 The labels for vehicles with a GVWR of 19,500 lb (8863 kg) or greater shall be a minimum of 5.7 in. long °¡ 4.2 in.

high (145 mm °¡ 107 mm). (52:15.2.11.1.2)

15.2.11.1.3 The marking in the label required by 15.2.11.1.1 shall consist of a border and the letters “CNGCH2” or “LNG,” as

appropriate [1 in. (25 mm) minimum height centered in the diamond] of silver or white reflective luminous material on a blue

background. (52:15.2.11.1.3)

15.2.11.1.4 The marking in the label required in 15.2.11.1.2 shall consist of a border and the letters “CNGCH2” or “LNG, ” as

15.2.11.1.5 The labels for 19,500 lb (8863 kg) GVWR and greater shall be a minimum of 5.7 in. long °¡ 4.2 in. high

(145 mm °¡ 107 mm). In addition to the requirement in 15.2.11.1.2 for placement of the diamond-shaped label on the lower right

rear of the vehicle, labels shall be affixed to each side of the power unit. If a DOT number is required to be

displayed in accordance with 49 CFR 390.21, then the labels shall be affixed near the DOT numbers on each side of the power

unit. (52:15.2.11.1.5)

15.2.11.1.6 Vehicles with roof-mounted CNGCH2 fuel containers shall include a permanent label in the drive’s compartment,

clearly visible to a seated operator, which includes the maximum total height of the unladen vehicle. (52:15.2.11.1.6)

15.3 CNGCH2 Engine Fuel Systems. 15.3.1 Scope. In addition to the general requirements of Section 15.2, the fuel specific requirements of Section 15.3

apply to fuel systems serving CNGCH2 fueled vehicles. (52:15.3.1)

15.3.1.1 Where there is a conflict between a general requirement and a fuel specific requirement, the fuel specific requirement

shall apply. (52:15.3.1.1)

15.3.2 System Component Qualifications. (52:15.3.2)

15.3.2.1 In addition to the requirements of Section 15.2, system components shall comply with the applicable provisions of

Chapter 15 and this section. (52:15.3.2.1)

15.3.2.2 Devices not otherwise specifically provided for shall be constructed to provide safety equivalent to that required for

other parts of a system. (52:15.3.2.2)

15.3.2.3 Temperature Range. Components in the engine compartment shall be designed or selected for a minimum temperature

range of −40°„F to 250°„F (−40°„C to 121°„C). (52:15.3.2.3)

15.3.2.4 System components shall comply with the applicable provisions of Chapter 15 and this section. (52:15.3.2.4

15.3.3 Installation of Fuel Supply Containers. 15.3.3.1 Containers. (52:15.3.3.1)

15.3.3.1.1 Fuel supply containers shall be protected with a means to prevent damage that occurs due to road hazards,

loading, unloading, direct sunlight, exhaust heat, and vehicle use, including accidental cargo leakage. (52:15.3.3.1.1)

15.3.3.1.2 Shields, if present, shall not interfere with the ability of the PRD to protect the fuel container. Shields shall be

installed in a manner that prevents damage to the container or its coating in the following occurrences: (52:15.3.3.1.2)

(1) Direct contact between the shield and the fuel supply container

(2) Trapping of solid materials or liquids between the shield and fuel supply container

15.3.3.1.3 The fuel supply container shall be positioned to prevent contact with vehicle components such as, but not limited

to, frame members, body panels, or brake lines that leads to container fretting or abrasion over time. (52:15.3.3.1.3)

15.3.3.1.4 Vehicle fuel supply containers shall be mounted in a location or shielded to minimize damage to the container, or

its valves and PRDs. (52:15.3.3.1.4)

15.3.3.1.4.1 Containers shall be protected by covers from accidental contact with overhead electrical wiring. (52:15.3.3.1.4.1)

15.3.3.1.4.2* The fuel system, including containers, shall be installed with as much road clearance as practical. (52:15.3.3.1.4.2)

15.3.3.1.4.3 The ground clearance shall be sufficient such that with the vehicle loaded to its gross vehicle weight rating, it would

not allow any component to touch the road surface in the event of a flat tire or the removal of any tire. (52:15.3.3.1.4.3)

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15.3.3.1.4.4 No portion of a fuel supply container or container appurtenance mounted on the undercarriage of the vehicle shall be

located ahead of the front axle or behind the point of attachment of the rear bumper to the vehicle. (52:15.3.3.1.4.4)

15.3.3.1.4.5 Any portion of the fuel supply container or its appurtenances on the exterior of the vehicle shall be provided

with a protective cover. (52:15.3.3.1.4.5)

15.3.3.1.5 Each fuel supply container shall be secured to the vehicle in a manner that minimizes the risk of damage from road

hazards, slippage, loosening, or transfer of vehicle chassis loads to the container due to frame flexing. (52:15.3.3.1.5)

15.3.3.1.6 Each fuel supply container shall be secured in a manner that it is capable of withstanding a static force, applied in the

six principal directions shown in Figure 15.3.3.1.6 of eight times the weight of the fully pressurized container. (52:15.3.3.1.6)

15.3.3.1.7 The fuel supply container weight shall not be supported by outlet valves, manifolds, or other fuel connections.

(52:15.3.3.1.7)

FIGURE 15.3.3.1.6 The Six Principal Directions.

15.3.3.1.8 Fuel supply containers shall be shielded against direct heat from any vehicle- or cargo-related source that would

result in normal operating container or PRD surface temperatures exceeding 180°„F (82°„C). (52:15.3.3.1.8)

15.3.3.1.9 The mounting system shall minimize fretting corrosion between the fuel supply container and the mounting system.

(52:15.3.3.1.9)

15.3.3.1.10 Fuel supply containers shall not be installed so as to adversely affect the driving characteristics of the vehicle.

(52:15.3.3.1.10)

15.3.3.1.11 Metal clamping bands and their supports shall not be in direct contact with a fuel supply container. (52:15.3.3.1.11)

15.3.3.1.11.1 A resilient gasket that does not adsorb water shall be installed between the clamping bands and their

supports and a container. (52:15.3.3.1.11.1)

15.3.3.1.11.2 The resilient gasket shall provide insulation to protect clamping bands from galvanic corrosion in contact with the

containers. (52:15.3.3.1.11.2)

15.3.3.1.12 Where a fuel supply container is located on a trailer, the fuel supply line shall contain an emergency breakaway

device designed to retain CNGCH2 on both sides of the breakaway point. 15.3.3.1.12)

15.3.3.1.13 Where parts of the vehicular fuel container are exposed to higher temperatures than the PRD during a localized

fire, the fuel container shall be protected by any of the following: (52:15.3.3.1.13)

(1) Noncombustible heat-insulating shielding to retard localized heating of the container

(2) Installation of a thermally sensitive “fusing” system to trigger the PRD in a fire situation

(3) Other design for venting of the fuel container in a fire situation

15.3.3.2 Installation of Relief Devices. PRDs shall be located so that the temperature to which they are subjected is representative

of the temperature to which the fuel supply container is subjected. (52:15.3.3.2)

15.3.3.3 Installation of Pressure Gauges. 15.3.3.3.1 Pressure gauges located within a driver or passenger compartment shall be installed in such a manner that no gas flows

into the passenger compartment in the event of failure. (52:15.3.3.3.1)

15.3.3.3.2 Pressure gauges installed outside a driver or passenger compartment shall be equipped with a limiting orifice, a

shatterproof lens, and a body relief. (52:15.3.3.3.2)

15.3.3.3.3 Pressure gauges shall be mounted, shielded, and installed in a protected location to prevent damage from vibration

and unsecured objects. (52:15.3.3.3.3)

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15.3.3.4 Installation of Pressure Regulators. 15.3.3.4.1 An automatic pressure-reducing regulator(s) shall be installed to reduce the fuel container pressure to a level

consistent with the working pressure required by the gas–air mixer, throttle body, or fuel injectors. (52:15.3.3.4.1)

15.3.3.4.2 Means shall be provided to prevent regulator malfunctions due to refrigeration effects. (52:15.3.3.4.2)

15.3.3.4.3 Regulators shall be installed so that their weight is not placed on, or supported by, the attached gas lines.

(52:15.3.3.4.3)

15.3.3.5 Installation of Fuel Lines. (52:15.3.3.5)

15.3.3.5.1 A pipe thread jointing material impervious to the action of the natural gashydrogen used in the system shall be applied

to all male pipe threads prior to assembly. (52:15.3.3.5.1)

15.3.3.5.2 Metallic tubing and fittings shall be clear and free from cutting or threading burrs and scales. (52:15.3.3.5.2)

15.3.3.5.2.1 The ends of all metallic tubing shall be deburred or prepared in accordance with the fitting manufacturer’s

recommendations. (52:15.3.3.5.2.1)

15.3.3.5.3 Where necessary to prevent abrasion, fuel lines passing through a panel shall be protected by grommets or

other protective devices. (52:15.3.3.5.3)

15.3.3.5.4 Fuel lines shall have clearance from the engine exhaust system to protect the fuel lines from excessive heat by durable

and effective means. (52:15.3.3.5.4)

15.3.3.5.5 Fuel lines shall be mounted, braced, and supported to minimize vibration. (52:15.3.3.5.5)

15.3.3.5.5.1 Fuel lines shall be protected against damage, corrosion, or breakage due to strain or wear. (52:15.3.3.5.5.1)

15.3.3.5.6 A bend in metallic tubing shall be prohibited where such a bend weakens the tubing. (52:15.3.3.5.6)

15.3.3.5.7 Mechanical joints on fuel line systems shall be located in an accessible location and shall not be located where natural

gashydrogen leakage can accumulate undetected. (52:15.3.3.5.7)

15.3.3.5.8 Aluminum or copper pipe, tubing, or fittings shall not be used between the fuel container and the first-stage pressure

regulator. (52:15.3.3.5.8)

15.3.3.6 Fuel-Subsystem Isolation. 15.3.3.6.1 Container Isolation. (52:15.3.3.6.1)

15.3.3.6.1.1 Every fuel container shall be equipped with either of the following: (52:15.3.3.6.1.1)

(1) A manual shutoff valve

(2) A normally closed, remotely actuated shutoff valve connected directly to the container

15.3.3.6.1.2 Vehicles with more than one fuel supply container, where each container is equipped with a normally closed

remotely actuated shutoff valve, shall have an automatic system to detect the failure of any one of the valves. (52:15.3.3.6.1.2)

15.3.3.6.1.3 When shut-off valves are attached directly to fuel containers, there shall be a means for the technician to determine

if there is still pressure in the container, regardless of the valve position. (52:15.3.3.6.1.3)

15.3.3.6.1.4 If an interconnected PRD system is protecting a group of containers installed in accordance with 15.3.3.8.7, a single

valve shall be permitted that will isolate the group of containers. (52:15.3.3.6.1.4)

15.3.3.6.1.5 A means shall be provided to bleed the container manually even in the event that a remote actuated shutoff valve

fails or an excess flow device should remain closed. (52:15.3.3.6.1.5)

15.3.3.6.2 Fuel System Isolation. In addition to the valve required by 15.3.3.6.1, a manual shutoff valve or a normally closed,

automatically actuated shutoff valve shall be installed that allows isolation of the container(s) from the remainder of the fuel

system. (52:15.3.3.6.2)

(A) An additional manual shutoff valve shall not be required on vehicles that are not normally operated on public streets,

that have a single fuel supply container, and that are equipped with an accessible manual container shutoff valve.

(B) The fuel system isolation valve shall be mounted and shielded or installed in a protected location to minimize damage from

vibration and unsecured objects.


(D) The manual shutoff valve shall have not more than 90 degrees rotation (quarter turn fuel delivery valve) from the open to the

closed positions.


(F) Where a manual shutoff valve is used, the valve location shall be indicated by means of a decal or label containing the words

“MANUAL SHUTOFF VALVE.”

(G) A weather-resistant decal or label with red, blue, or black letters on a white or silver reflective background shall be used.

(H) The valve required by 15.3.3.6.2 shall not be used to introduce high-pressure gas to downstream components of the fuel

system that have previously been depressurized.

15.3.3.6.3 Engine Isolation. A valve fuel injector, or other means shall be provided that automatically prevents the flow of

gaseous fuel to the engine when the engine is not running, even if the ignition is switched on. (52:15.3.3.6.3)

15.3.3.6.4* Multiple Fuel Systems. Where multiple fuel systems are installed on the vehicle, automatic valves shall be provided, as necessary, to shut off the fuel not

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being used.

15.3.3.6.5 Fuel Backflow Prevention. The fueling system shall be equipped with a backflow check valve that prevents the return flow of gas from the container(s) to

the filling connection.

15.3.3.6.5.1 The backflow check valve shall be mounted to withstand the breakaway force specified in 8.4.2.4. (52:15.3.3.6.5.1)

15.3.3.6.5.2 A second check valve shall be located between the fueling receptacle and the fuel supply containers.

(52:15.3.3.6.5.2)

15.3.3.7 Installation of Fueling Connectors. 15.3.3.7.1 Fueling connections installed on vehicles less than 10,000 lb (4500 kg) gross vehicle weight rating (GVWR) shall

be in accordance with 14.4.2.7. (52:15.3.3.7.1)

15.3.3.7.2 Larger vehicles such as buses and trucks shall be permitted to use fueling connections that are designed to prevent the

connection of a lower service pressure vehicle to a higher service pressure source. (52:15.3.3.7.2)

15.3.3.7.3 The fueling connection receptacle shall be mounted to withstand the breakaway force specified in 8.4.2.4.

(52:15.3.3.7.3)

15.3.3.7.4 The receptacle shall be installed in accordance with the manufacturer’s instructions. (52:15.3.3.7.4)

15.3.3.7.5 The clearance around the fueling connection shall be free of interference that prevents the connection of the fueling

nozzle. (52:15.3.3.7.5)

15.3.3.8* Installation of PRD Systems. 15.3.3.8.1 All PRDs shall be in direct communication with the fuel. (52:15.3.3.8.1)

15.3.3.8.2 PRD manifolds connecting two or more containers shall be permitted if in accordance with the container

manufacturer’s instructions. (52:15.3.3.8.2)

15.3.3.8.3 The PRD for the protection of the container shall be installed in the same vehicle compartment as the container.

(52:15.3.3.8.3)

15.3.3.8.4 PRD Venting. (52:15.3.3.8.4)

15.3.3.8.4.1* The discharge from the PRD shall be vented to the outside of the vehicle. (52:15.3.3.8.4.1)

15.3.3.8.4.2 Vent tube or hose shall be electrically conductive. (52:15.3.3.8.4.2)

15.3.3.8.4.3 Vent tube or hose shall be secured at intervals in such a manner as to minimize the possibility of damage, corrosion,

or breakage of either the vent line or the pressure relief device due to expansion, contraction, vibration, strains, or wear and to

preclude any loosening while in operation. (52:15.3.3.8.4.3)

15.3.3.8.4.4 Vent tube or hose shall have a burst pressure of at least 1.5 times the pressure in the vent that results from activation

of the PRD. (52:15.3.3.8.4.4)

15.3.3.8.4.5 Vent(s) shall not discharge: (52:15.3.3.8.4.5)



(3) Toward CNGCH2 storage systems




(7) Toward an emergency exit

15.3.3.8.5 The vent opening shall not be blocked by debris thrown up from the road, such as snow, ice, mud, and so on, or

otherwise affected by the elements. (52:15.3.3.8.5)

15.3.3.8.6 Vent opening(s) shall resist accumulation of water due to rain, vehicle washing, and moisture due to condensation.

(52:15.3.3.8.6)

15.3.3.8.7 Vent opening(s) shall not restrict the operation of a container pressure relief device or pressure relief device channel.

(52:15.3.3.8.7)

15.3.3.9 Vent Outlet Protection. (52:15.3.3.9)

15.3.3.9.1 Means shall be provided to prevent water, dirt, insects, and any foreign objects from collecting in the vent lines or

pressure relief devices. (52:15.3.3.9.1)

15.3.3.9.2 Protective devices in 15.3.3.9.1 shall not restrict the flow of gas. (52:15.3.3.9.2)

15.3.3.10* Vent Location and Signage. For vehicles with GVWR in excess of 19,500 lb (8863 kg), the following shall apply:



15.3.3.10.1 A safety sign(s) as depicted in Figure 15.3.3.10.1 shall indicate the PRD vent location. (52:15.3.3.10.1)

15.3.3.10.2 Each safety sign shall be 3 in. tall by 5 in. wide and shall use 18 point san serif font for the message text.

(52:15.3.3.10.2)

15.3.3.10.3 One safety sign shall be located near each vent area. (52:15.3.3.10.3)

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15.3.3.11 Gastight Enclosures. 15.3.3.11.1 The neck of the container and all CNGCH2 fittings within the compartment shall be enclosed in a gastight enclosure

made of linear, low-density polyethylene having a minimum thickness of 8 mils (0.20 mm) or an equally gastight alternate

enclosure that is vented directly to the outside of the vehicle. (52:15.3.3.11.1)

15.3.3.11.2 The gastight enclosure shall not be constructed of fire-resistant material. (52:15.3.3.11.2)

15.3.4 Discharge from Vehicle Containers. 15.3.4.1 The venting or depressurization of a CNGCH2 container shall be performed only by trained personnel using written

procedures. (52:15.3.4.1)

15.3.4.1.1 The gas to be removed from the container shall be discharged into a closed transfer system or vented by an approved

method of atmospheric venting. (52:15.3.4.1.1)

15.3.4.1.2 A valve shall be used to control the discharge of gas from high-pressure systems to a venting system. (52:15.3.4.1.2)

15.3.4.2 Personnel training container depressurization shall do the following: (52:15.3.4.2)



(3) Limit the rate of gas release from plastic-lined containers to a value not greater than that specified by the container

manufacturer


15.3.4.3 Direct gas venting shall be done through a vent tube that diverts the gas flow to atmosphere. (52:15.3.4.3)

15.3.4.3.1 The vent tube shall have a gastight connection to the container prior to venting. (52:15.3.4.3.1)

15.3.4.3.2 All components of the vent tube shall be grounded. (52:15.3.4.3.2)

WARNING CNGCH2 Vent Hazard

During vehicle fire:

Keep people away

Prepare for large flame

Let fire burn

Gas vents here

Failure to comply may injure

or kill. FIGURE 15.3.3.10.1

15.3.5 Container Inspections. 15.3.5.1* Where a vehicle is involved in an accident or fire causing damage to the CNGCH2 container, or if the container is

subjected to a pressure greater than 125 percent of service pressure, the CNGCH2 container shall be replaced, inspected, or

retested in accordance with the vehicle or container manufacturer’s instructions. The mechanic performing the replacement,

removal, inspection, and/or retesting shall prepare a document certifying that the cylinder is acceptable for return

to service and present the document to be retained by the vehicle owner/operator and a copy to be retained by himself. The

document shall identify the vehicle, (by license plate number or vehicle identification number) and the cylinder (by serial

number); describe the work done and the dates of work; and provide the mechanic’s name and contact information. (52:15.3.5.1)

15.3.5.2 Where a vehicle is involved in an accident or fire causing damage to any part of the CNGCH2 fuel system, the system

shall be repaired and retested (see Section 15.3.8) before being returned to service. The mechanic performing the repair and

retesting shall prepare a document certifying that the CNGCH2 fuel system is acceptable for return to service and present the

document to be retained by the vehicle’s owner/operator and a copy to be retained by himself. The document shall identify the

vehicle (by license number or vehicle identification number) parts of the CNGCH2 fuel system worked on; describe the work

done and dates of work; and provide the mechanic’s name and contact information. (52:15.3.5.2)

15.3.5.3 Where a CNGCH2 container is removed from a vehicle to be installed within a different vehicle, it shall be inspected or

retested in accordance with the vehicle or container manufacturer’s inspection or requalification procedures before it is

reinstalled. (52:15.3.5.3)

15.3.6 Labeling. 15.3.6.1 A vehicle equipped with a CNGCH2 fuel system shall bear the following permanent labels: (52:15.3.6.1)



(b) System designed and installed in conformance with NFPA 52-XXXX (insert the edition year of the code)


(d) Installer/converter’s name or company and contact information (i.e., address, telephone number, and email)

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(c) Fuel container life expiration (insert date for limited-life fuel containers. This label item is not required for containers with

unlimited life.)

(d) “Fuel containers are to be inspected by (insert date) and each (insert number) months thereafter.”




15.3.6.1.1 The fuel container inspection dates shall be changed after each required container inspection to denote the next

required inspection date. (See Section 15.3.9 for inspections). (52:15.3.6.1.1)

15.3.6.2 In addition to the label(s) required by 15.3.6.1, each vehicle shall be identified with a permanent, diamond-shaped

label located on the exterior vertical surface or near-vertical surface on the lower right rear of the vehicle other than on the

bumper of the vehicle. (52:15.3.6.2)

15.3.6.2.1 The labels for vehicles less than 19,500 lb (8863 kg) GVWR shall be a minimum of 4.72 in. long °¡ 3.27 in. high (120

mm long °¡ 83 mm high). (52:15.3.6.2.1)

15.3.6.2.2 The labels for vehicles with a GVWR of 19,500 lb (8863 kg) or greater shall be a minimum of 5.7 in. long °¡ 4.2 in.

high (145 mm long °¡ 107 mm high). (52:15.3.6.2.2)

15.3.6.2.3 The marking in the label required by 15.2.11.1.1 shall consist of a border and the letters “CNGCH2” [1 in. (25 mm)

minimum height centered in the diamond] of silver or white reflective luminous material on a blue background. (52:15.3.6.2.3)

15.3.6.2.4 The marking in the label required by 15.2.11.1.2 shall consist of a border and the letters “CNGCH2” [1.2 in.

(30 mm) minimum height centered in the diamond] in silver or white reflective luminous material on a blue background. In

addition to placement of the “CNGCH2” diamond label on the right rear of the vehicle, the “CNGCH2” diamond label shall also

be

affixed to both sides of the power unit. If a DOT number is required to be displayed in accordance with 49 CFR 390.21,

then the labels shall be affixed near the DOT numbers on each side of the power unit. (52:15.3.6.2.4)

15.3.6.2.5 Vehicles with roof-mounted CNGCH2 fuel containers shall include a permanent label in the driver's compartment,

clearly visible to a seated operator, which includes the maximum total height of the unladen vehicle. (52:15.3.6.2.5)

15.3.6.3 Each assembly of CNGCH2 containers shall be permanently labeled near the container valve as follows:

DANGER. Venting of the pressure from this system requires the use of special instructions or tools that can be obtained from

the manufacturer [Insert the name, telephone number, and email address of the vehicle manufacturer or system installer].

(52:15.3.6.3)

15.3.7 Permanent labels shall meet the requirements of ANSI/UL 969, Standard for Marking and Labeling Systems. (52:15.3.7)

15.3.8 System Testing. 15.3.8.1* The completed fuel system assembly shall be leak tested using natural gashydrogen or inert gas. (52:15.3.8.1)

15.3.8.2 Before use, every connection not previously tested in subassemblies shall be inspected for leaks with a noncorrosive

leak detector solution or a leak detector instrument after the equipment is connected and pressurized to its service pressure.

Passing inspection shall require the following: (52:15.3.8.2)


(2) Any leakage as noted in 15.3.8.2(1) shall be corrected; and

(3) The system shall be leak-checked again after any corrections, modifications, disassembly, repairs or replacement of

components of the natural gashydrogen system.

15.3.8.3 If the completed assembly is leak tested with natural gas, the testing shall be done under ventilated conditions.

(52:15.3.8.3)

15.3.9 System Inspection, Maintenance, and Repair. (52:15.3.9)

15.3.9.1 Damaged fuel lines shall be replaced and not repaired. (52:15.3.9.1)

15.3.9.2 All containers, container appurtenances, piping systems, venting systems, and other components shall be maintained

in accordance with the manufacturer's requirements. (52:15.3.9.2)

15.3.9.3* Vehicle supply containers shall be inspected in accordance with the schedule in the vehicle label required in

15.3.6 and one of the following: (52:15.3.9.3)



(3) The instructions in CGA C-6.4, Methods for External Visual Inspection of Natural Gas Vehicle (NGV) and Hydrogen Vehicle

((HGV) Fuel Containers and Their Installations. Personnel inspecting vehicle fuel supply containers shall be trained on CGA C-

6.4.

15.3.9.3.1 Fuel containers whose service life has expired shall be removed from service. (52:15.3.9.3.1)

15.3.9.3.2 After periodic container inspection, a label showing the next required inspection date shall be affixed as required

in 15.3.6.1. (52:15.3.9.3.2)

15.3.9.4 Pressure relief devices on fuel containers shall be maintained in accordance with the following: (52:15.3.9.4)

(1) Pressure relief device channels or other parts that interfere with the functioning of the device shall not be plugged by paint or

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accumulation of dirt.


(3) No pressure relief valve that has been in service shall be repaired or reworked without the written authorization of the

pressure relief device manufacturer, valve manufacturer, fuel container manufacturer, or vehicle manufacturer. Any device that

has been activated shall not be reworked or reused and shall be removed from service.


15.3.9.5 The following shall be done during vehicle maintenance: (52:15.3.9.5)

(1) Ensure the engine is isolated from the fuel supply unless engine operation is required. If a manual isolation valve is used, it

shall comply with 15.3.3.6.2.

(2) Prohibit torches, welding, or grinding equipment on or near high-pressure fuel lines and containers.

(3) Prevent damage to containers, including actions such as dropping, dragging, or rolling of the container.

(4) Prevent exposure of containers to strong chemicals such as battery acid or metal-cleaning solvents.

(5) Store CNGCH2 containers in a manner to avoid damage.



(8) The openings in all stored cylinders shall be closed to prevent the entry of moisture and other contaminants.

(9) Reinstall containers to their original configuration using approved gaskets, bolts, nuts, washers, and parts in

accordance with the recommendations of the vehicle or container manufacturer or system installer.


(11) Prohibit personnel from walking on containers unless permitted by the container manufacturer.

15.3.9.6 OEMs, FSVIMs, alterers, and converters shall make available instructions for system maintenance and repair.

(52:15.3.9.6)

15.3.9.7 Qualified Mechanic. 15.3.9.7.1 All personnel engaged in activities in 15.3.4, 15.3.8, and 15.3.9, namely, discharging CNGCH2 fuel containers or

maintenance, repair, replacement, removal, and testing of CNGCH2 fuel system or its components shall be qualified mechanics.

(52:15.3.9.7.1)

15.3.9.7.2 A qualified mechanic shall meet the definition of qualified person. (52:15.3.9.7.2)

15.4 LNG Engine Fuel Systems.

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Public Input No. 343-NFPA 2-2016 [ Chapter A [Excluding any Sub-Sections] ]

Annex A is not a part of the requirements of this NFPA document but is included for informational purposes only. This annex contains explanatory material,numbered to correspond with the applicable text paragraphs.

A.18.7.5 See A.6.16.







Public Input No. 342-NFPA 2-2016 [New Section after 18.7.5] Same topic/need





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Public Input No. 304-NFPA 2-2016 [ Section No. A.3.3.117 ]

A.3.3.117 Hydrogen Equipment Enclosure (HEE).

Hydrogen equipment enclosures can include repurposed “shipping” or “ISO” containers as defined in Section 3.3.8 of NFPA 307: A reusable, intermodalboxlike structure of rigid construction fitted with devices to permit lifting and handling particularly transfer from one mode of transportation to another modeof transportation.

Hydrogen equipment located in enclosures larger than the largest standard intermodal container (presently 56 ft. long x 8 ft. wide x 9.5 ft. high) typically aresubject to the requirements for indoor installations.

Hydrogen equipment enclosures include those used for equipment that process or store hydrogen. Enclosures can be for weather protection, aesthetictreatment, security, or to prevent external damage. Exterior enclosure walls are not typically intended to carry a fire resistance rating. The HEE may bedesigned to contain and control potential hydrogen leaks from hydrogen storage, compressors and other hydrogen fuel processing equipment, exteriorwalls may contain fire rating.

Enclosures can be enterable but are not intended to be occupied. Hydrogen equipment in enclosures in laboratories are covered by Section 6.19.


this change in definition was developed by the NFPA 2 Task Force on HEE




Affilliation: on Behalf of Linde and the NFPA 2 HEE Task Group

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Public Input No. 388-NFPA 2-2016 [ Section No. A.6.4.1.5.1 ]

A.6.4.1.5.1

Occupancies including industrial and storage occupancies are defined by the building code adopted by the jurisdiction. Occupancy is a term used todefine the activity or purpose of a building or space within a building where activity occurs. In general, occupancies are separated into various categoriesdepending on the use. Some of the categories, depending on the adopted building code, can include but are not limited to the following: assembly,business, educational, factory (or industrial), hazardous, institutional, mercantile, residential, storage, etc. Construction features as well as engineeringcontrols are influenced by the occupancy. The greater the hazard, the more restrictive the controls to be applied within the context of construction featuresand engineering controls integral to the use of the building. Limitations are placed on building heights, areas, construction types, and construction features,including building or area exits and the egress system in general, depending on the risk based on a predefined set of conditions imposed by the occupancycategory. Industrial occupancies are typically involved with manufacturing of a product and involve factories and workshops used to manufacture orprocess a wide array of materials. A storage occupancy is one in which manufactured goods are stored. Activity in these areas is limited to the storage ofgoods or materials. The quantity of hazardous materials in occupancies other than those classified as hazardous is limited. When the need for quantity ofvarious hazardous materials including hydrogen increases, the occupancy of the area can revert to that of a “hazardous occupancy,” or the excessquantities might have to be isolated from the factory floor by either placing them into a room that is isolated by fire-resistive construction, or by transferringthe materials outside of the building or to a separate building where they can be piped to a point of use.


This section this annex note is related to is recommended for deletion for being overly restrictive and presenting a road block to hydrogen technology. A simple example is use of hydrogen in a laboratory which is classified as either a business or educational occupancy. This topic is best regulated by the adopted building and fire codes which include thresholds for varied levels of protection.



Public Input No. 387-NFPA 2-2016 [Section No. 6.4.1.5.1 [Excluding any Sub-Sections]] Tethered





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Public Input No. 359-NFPA 2-2016 [ New Section after A.6.17 ]

A.6.17.2.1.7 The make-up air intake inlets to the exhaust systems shall be designed to prevent blockage due to debris, foliage, ice, snow, etc. to ensureeffective air intake.







Public Input No. 358-NFPA 2-2016 [Sections 6.17.1, 6.17.2] Part of a package





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Public Input No. 49-NFPA 2-2016 [ Section No. A.7.3.2.3.1.1 ]

SEE SUBSTANTIATION and ATTACHMENTS for PROPOSED CHANGES - THIS WAS A Public Comment HELD from LAST CYCLE

A .7.3.2.3.1.1

Conversions for distance between inch-pound and SI units of measure cannot be consistently performed using typical mathematical conversion factors. Themajority of separation distances shown in the SI table have been determined by the application of a risk-informed approach substantiated by statisticalevaluation and modeling based on validated models for both ignited and unignited release of hydrogen gas. Where distance has been determined to allowfor access or for correlation with the electrical code, the distances were not established through the use of models. Tabular distances in the inch-poundtable have been determined by first converting SI units into inch-pound units and then rounding the distance to the nearest 5 ft for ease of application bycode enforcers and users. A similar rounding technique has not been applied in the tabular distances shown in the SI table.

The exposures integral to Table 7.3.2.3.1.1(a), Exposure Group 1(a) Table 7.3.2.3.1.1(b) , and Table 7.3.2.3.1.1(c) have been arranged into groups basedon similar risks. The thresholds are applicable to the exposures identified in each group, as follows: [55:A.10.4.2.2.1]

(1) Group 1 Exposures. The distances specified are those required to reduce the radiant heat flux level to 500 Btu/hr / ft2 (1577 W/m2) at the propertyline or the distance to a point in the unignited hydrogen jet where the hydrogen content is reduced to a 4 percent mole fraction (volume fraction) ofhydrogen, whichever is greater. In all cases the distance required to achieve a 4 percent mole fraction was the greater distance and used to establish therequirements. [55:A.10.4.2.2.1]

(2) Group 2 Exposures. The distances specified are those required to reduce the radiant heat flux level to 1500 Btu/hr / ft2 (4732 W/m2) for personsexposed a maximum of 3 minutes. [55:A.10.4.2.2.1]

(3) Group 3 Exposures. The distances specified are those required to reduce the radiant heat flux level to 6340 Btu/hr / ft2 (20,000 W/m2) or the visible

flame length for combustible materials, or a radiant heat flux level of 8000 Btu/hr / ft2 (25,237 W/m2) or the visible flame length for noncombustibleequipment. In both cases the visible flame length was used to establish the requirements. [55:A.10.4.2.2.1]

Table 7.3.2.3.1.1(a) Exposure Group 1(a). Lot lines (property lines) are those property lines between parcels and should not be construed to be theimaginary property lines that are drawn for the purposes of protecting the exterior walls of multiple buildings placed on the same lot or parcel. Railroadeasements that are not accessible to the public other than by rail travel can be used as a means of spatial separation, with the required separation beingmeasured between the hydrogen system and the nearest railroad track. It should be noted that in these cases, the addition or relocation of track may resultin an encroachment that will necessitate relocation of the hydrogen system at the system user’s expense. [55:A.10.4.2.2.1]

Where the property on the other side of a property line is determined to be unbuildable or unoccupiable due to natural features including, but not limited to,waterways, terrain, wetlands, or similar features encroachment by the hydrogen system on the property line can be acceptable with the approval of theauthority having jurisdiction. Should the property that is encroached upon become buildable or otherwise occupiable, the hydrogen system location shouldbe reevaluated by the system user and the AHJ notified of the results. [55:A.10.4.2.2.1]

Table 7.3.2.3.1.1(a) Exposure Group 2(a). The exposed persons of concern are non-work-related persons or members of the public who are not involvedwith servicing the system, because these persons typically are neither trained nor knowledgeable in the operation of the system, but are on the premises.By comparison, service personnel or those involved with servicing the system are trained and engaged in activities related to the system operationincluding, but not limited to, inspecting, monitoring system inventory, delivering product, maintenance, or similar functions. Administrative controls,engineering controls, or construction features are typically used to restrict persons other than service personnel from being within the zone of potentialexposure. The permit holder is responsible for managing and administering the controls to restrict access. Examples of such controls could include paintedlines or signs or physical barriers such as a fence. [55:A.10.4.2.2.1]



Held_PC_46.pdf NFPA 2 _PC 46


NOTE: This Public Input appeared as "Reject But Held" in Public Comment No. 46 (A2015 Cycle) Second Draft Report for NFPA 2 and per the Regs. at 4.4.8.3.1.

The paragraph on rounding to next 5 feet, etc. does not appear to apply to the new tables. Changed references to section and tables to correlate with proposed change (see Public Comment No. 44).


Submitter Full Name: Tc On Hyd-Aaa

Organization: NFPA

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Public Comment No. 46-NFPA 2-2014 [ Section No. A.7.3.2.3.1.1(A) ]

A.7.3.2.3.1.1 (A)

Conversions for distance between inch-pound and SI units of measure cannot be consistently performed usingtypical mathematical conversion factors. The majority of separation distances shown in the SI table have beendetermined by the application of a risk-informed approach substantiated by statistical evaluation and modelingbased on validated models for both ignited and unignited release of hydrogen gas. Where distance has beendetermined to allow for access or for correlation with the electrical code, the distances were not establishedthrough the use of models. Tabular distances in the inch-pound table have been determined by first convertingSI units into inch-pound units and then rounding the distance to the nearest 5 ft for ease of application by codeenforcers and users. A similar rounding technique has not been applied in the tabular distances shown in the SItable.

The

The exposures integral to Table 7.3.2.3.1.1(A)( a) , Exposure Group 1(a) Table 7.3.2.3.1.1(A)( b), and Table7.3.2.3.1.1(A)( c) have been arranged into groups based on similar risks. The thresholds are applicable to theexposures identified in each group, as follows: [55:A.10.3.2.1]

(1) Group 1 Exposures. The distances specified are those required to reduce the radiant heat flux level to

500 Btu/hr / ft2 (1577 W/m2) at the property line or the distance to a point in the unignited hydrogen jet wherethe hydrogen content is reduced to a 4 percent mole fraction (volume fraction) of hydrogen, whichever isgreater. In all cases the distance required to achieve a 4 percent mole fraction was the greater distance andused to establish the requirements. [55:A.10.3.2.1]


1500 Btu/hr / ft2 (4732 W/m2) for persons exposed a maximum of 3 minutes. [55:A.10.3.2.1]


6340 Btu/hr / ft2 (20,000 W/m2) or the visible flame length for combustible materials, or a radiant heat flux level

of 8000 Btu/hr / ft2 (25,237 W/m2) or the visible flame length for noncombustible equipment. In both cases thevisible flame length was used to establish the requirements. [55:A.10.3.2.1]

Table 7.3.2.3.1.1(A)( a) Exposure Group 1(a). Lot lines (property lines) are those property lines betweenparcels and should not be construed to be the imaginary property lines that are drawn for the purposes ofprotecting the exterior walls of multiple buildings placed on the same lot or parcel. Railroad easements that arenot accessible to the public other than by rail travel can be used as a means of spatial separation, with therequired separation being measured between the hydrogen system and the nearest railroad track. It should benoted that in these cases, the addition or relocation of track may result in an encroachment that will necessitaterelocation of the hydrogen system at the system user’s expense. [55:A.10.3.2.1]

Where the property on the other side of a property line is determined to be unbuildable or unoccupiable due tonatural features including, but not limited to, waterways, terrain, wetlands, or similar features encroachment bythe hydrogen system on the property line can be acceptable with the approval of the authority havingjurisdiction. Should the property that is encroached upon become buildable or otherwise occupiable, thehydrogen system location should be reevaluated by the system user and the AHJ notified of the results.[55:A.10.3.2.1]

Table 7.3.2.3.1.1(A)( a) Exposure Group 2(a). The exposed persons of concern are non-work-related personsor members of the public who are not involved with servicing the system, because these persons typically areneither trained nor knowledgeable in the operation of the system, but are on the premises. By comparison,service personnel or those involved with servicing the system are trained and engaged in activities related tothe system operation including, but not limited to, inspecting, monitoring system inventory, delivering product,maintenance, or similar functions. Administrative controls, engineering controls, or construction features aretypically used to restrict persons other than service personnel from being within the zone of potential exposure.The permit holder is responsible for managing and administering the controls to restrict access. Examples ofsuch controls could include painted lines or signs or physical barriers such as a fence. [55:A.10.3.2.1]


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Statement of Problem and Substantiation for Public Comment

The paragraph on rounding to next 5 feet, etc. does not appear to apply to the new tables.

Changed references to section and tables to correlate with proposed change (see Public Comment No. 44).

Related Public Comments for This Document

Related Comment Relationship

Public Comment No. 44-NFPA 2-2014 [Section No.7.3.2.3.1.1]

This Annex A entry refers to section and tables modifiedby PC No. 44.

Related Item

First Revision No. 362-NFPA 2-2013 [Section No. 7.3.2.3.1.1]


Submitter Full Name: Stephen Goyette

Organization: Nuvera Fuel Cells, Inc.

Affilliation: NFPA 2 committee

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Committee Statement

CommitteeAction:

Rejected but held

Resolution: The committee would like to review this issue further in the next revision cycle and determine if the firstparagraph is still applicable to the tables. The renumbering of the tables will be completed by editorialonce those changes are made. This should be submitted as a public input during the next revision cycleof NFPA 55 and extracted appropriately into NFPA 2

Copyright Assignment

I, Stephen Goyette, hereby irrevocably grant and assign to the National Fire Protection Association (NFPA) all and full rights in copyright in thisPublic Comment (including both the Proposed Change and the Statement of Problem and Substantiation). I understand and intend that I acquireno rights, including rights as a joint author, in any publication of the NFPA in which this Public Comment in this or another similar or derivativeform is used. I hereby warrant that I am the author of this Public Comment and that I have full power and authority to enter into this copyrightassignment.

By checking this box I affirm that I am Stephen Goyette, and I agree to be legally bound by the above Copyright Assignment and the termsand conditions contained therein. I understand and intend that, by checking this box, I am creating an electronic signature that will, upon mysubmission of this form, have the same legal force and effect as a handwritten signature


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Public Input No. 349-NFPA 2-2016 [ Section No. A.10.2.1.2 ]

A.10.2.1.2

A hazard(s) analysis can be performed by a number of methods where the end result can be achieved through the use of more than one method. Several ofthe more common methods employed by those involved in systems safety today include, but are not limited to, hazard and operability studies (HAZOPs),failure modes effects and criticality analysis (FMECA), preliminary hazards analysis (PHA), fault tree analysis (FTA), and event tree analysis. Standarddesigns that have been analyzed by recognized methodology need not be studied each and every time such an installation occurs. Rather, site-specificelements that are unique to the installation should be reviewed in concert with the analysis performed on the standard system to ensure that the standarddesign has not been altered in a way that would negatively affect the hazard analysis.

The reviews conducted frequently involve a series of meetings between members of a multidisciplinary team that methodically “brainstorms” the systemdesign, following a structure provided by study format and the team leader’s experience. Members of the team can include engineers as well as otherpersonnel skilled in the application of a systems safety approach.


Reason: This proposal takes guidance language from the annex note and places that language within the body of the code to provide specific enforceable language, rather than just guidance to eliminate unnecessary costs for redundant analysis.



Public Input No. 348-NFPA 2-2016 [Section No. 10.2.1.2] Direct. Language from Annex note goes to Chapter 10.





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A.10.3.1.1

It is acknowledged that with a developing technology not all components included in 10.3.1.1 have listing standards to be listed to. The purpose of thelanguage “listed or approved” is to require listing documentation for those items for which listing standards exist, and for an appropriate amount ofdocumentation proving suitability and safety of the intended use be provided to the AHJ to allow for the “approval” of components that do not have listings. Dispensers can be listed and certified to meet the requirements of ANSI/CSA HGV 4.1.


Reason: The added language is to further clarify the concept of "listed or approved" as it relates to components of systems, some of which will have listing standards, and some that will not.





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A.10.3.1.1

Dispensers can be The following are examples of standards that can be used for listing or certification:

(1) Valves can be listed and certified to meet the requirements of ANSI/CSA HGV 4. 6 or ANSI/CSA HGV 4.7.

(2) Hoses can be listed and certified to meet the requirements of ANSI/CSA HGV 4.2.

(3) Hydrogen dispensers can be listed and certified to meet the requirements of ANSI/CSA HGV 4. 1.

(4) Breakaway devices can be listed and certified to meet the requirements of ANSI/CSA HGV 4.4.

(5) Compressors can be listed and certified to meet the requirements of ANSI/CSA HGV 4.8.

(6) Fittings can be listed and certifed to meet the requirements of ANSI/CSA HGV 4.10.


Additional CSA standards for valves, hoses, breakaway devices, compressors and fittings allows guidance to the user of NFPA 2. These additional system or system components included to Section A.10.3.1.1 is consistent with the text already present in A.10.3.1.1 for dispensers.



Public Input No. 311-NFPA 2-2016[Section No. 10.3.1.1]

PI #311 proposes to add compressors and fittings to the list of system component qualifications in Section 10.3.1.1. PI#68 proposes to add examples of standards that can be used for listing or certification.

Public Input No. 73-NFPA 2-2016[New Section after M.1.2.6]

PI #68 proposes to add examples of standards that can be used for listing or certification. PI #73 proposes to addthese new CSA Group Standards to Section M.1.2.




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A.10.3.3.2.3

A generic dispenser piping and instrumentation diagram with NFPA 2 references is provided to help the user to apply the requirements. See FigureA.10.3.3.2.3.

Figure A.10.3.3.2.3 Indoor Nonpublic Fast-Fill Dispenser P & ID.



Figure_A.10.3.3.2.3.jpg Figure A.10.3.3.2.3


Update Figure A.10.3.3.2.3 P&ID Tag BC1 to correct reference from NGV 4.4 (natural gas) to HGV 4.4 (hydrogen) standard.




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Public Input No. 69-NFPA 2-2016 [ Section No. A.12.2 ]

A.12.2

Fuel cell technology is evolving at a rapid rate, and codes and standards criteria are needed to help acceptance of the new technology. Currently, there isonly one standard for testing stationary fuel cell power systems, which is ANSI/ CSA FC.1, American National Standard for Fuel Cell Power Systems. ANSIFuel cell technologies - Part 3-100: Stationary fuel cell power systems - Safety . ANSI/ CSA FC.1 applies to a specific size fuel cell power system that isprepackaged and assembled as one complete unit. The constraints of ANSI/ CSA FC.1 limit the ability to test and list larger power plants or power systemsthat use fuels other than natural gas or LP-Gas or that are not prepackaged and self-contained.

NFPA 853 provides additional guidance for acceptance of power system installations that are not within the scope of ANSI/ CSA FC.1, commensurate withthe need to protect life safety and property and the need of the adoption agencies to be able to uniformly evaluate power system installations outside thescope of available equipment standards. [853: A.4.1]


Correction to CSA Group Standard designation and title.




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A.12.3.2.1.1

ANSI/CSA FC 3, American National Standard / CSA American Standard for Portable Fuel Cell Power Systems, applies to ac- and dc-type portable fuel cellpower systems, with a rated output voltage not exceeding 600 volts, for commercial, industrial, and residential indoor and outdoor use in nonhazardouslocations, in accordance with NFPA 70. ANSI/ CSA FC3 FC 3 does not apply to portable fuel cell power systems that are permanently connected(stationary) to either fuel or electric supply, designed to export power to a grid, replacement fuel cell power units for appliances, or fuel cell systems forpropulsion. Additional guidance pertaining to portable fuel cell power systems is provided by IEC 62282-5-1, Portable Fuel Cell Power Systems, Safety.


Correction to CSA Group Standard designation and title.




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A.16.2.2.1

A qualified design professional and owner safety officer should review the laboratory conditions through a hazard analysis and/or risk assessment todetermine if a hazardous (ignitable) atmosphere could be developed within the laboratory work area, laboratory area, laboratory unit, and/or fume hood. If ahazardous atmosphere could be developed, these areas should be electrically classified per NFPA 70, Article 500 [or Article 505] . [45: A.5.6.2]









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Public Input No. 71-NFPA 2-2016 [ Section No. J.2 ]

J.2 Electrical Design Standards for Vacuum Furnace Manufacturers.

The following is a list of electrical associations whose publications can be used as a guide for safe installation and application of electrical equipment andinstallation:

(1) National Fire Protection Association (NFPA), publisher of NFPA 70

(2) National Electrical Manufacturer’s Association (NEMA)

(3) Joint Industrial Council (JIC)

(4) Electronic Industries Association (EIA)

(5) Canadian Standards Association CSA Group (CSA)

(6) FM Global

[86: L.2]


Correction to CSA Group organization name.




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Public Input No. 5-NFPA 2-2016 [ Chapter M ]

Annex M Informational References

M.1 Referenced Publications.

The following documents or portions thereof are referenced within this code for informational purposes only and are thus not part of the requirements of thisdocument unless also listed in Chapter 2.

M.1.1 NFPA Publications.


NFPA 1, Fire Code, 2015 edition.

NFPA 25, Standard for the Inspection, Testing, and Maintenance of Water-Based Fire Protection Systems, 2014 edition.



NFPA 34, Standard for Dipping, Coating, and Printing Processes Using Flammable or Combustible Liquids, 2015 edition.


NFPA 49, Hazardous Chemicals Data, 1994 edition.

NFPA 50A, Standard for Gaseous Hydrogen Systems at Consumer Sites, 1999 edition.

NFPA 51, Standard for the Design and Installation of Oxygen–Fuel Gas Systems for Welding, Cutting, and Allied Processes, 2013 edition.




NFPA 70 ®, National Electrical Code ®, 2014 edition.

NFPA 77, Recommended Practice on Static Electricity, 2014 edition.


NFPA 90A, Standard for the Installation of Air-Conditioning and Ventilating Systems, 2015 edition.


NFPA 92, Standard for Smoke Control Systems, 2015 edition.

NFPA 101 ®, Life Safety Code ®, 2015 edition.

NFPA 220, Standard on Types of Building Construction, 2015 edition.


NFPA 307, Standard for the Construction and Fire Protection of Marine Terminals, Piers, and Wharves, 2015 edition.

NFPA 325, Guide to Fire Hazard Properties of Flammable Liquids, Gases, and Volatile Solids, 1994 edition.

NFPA 491, Manual of Hazardous Chemical Reactions, 1997 edition.

NFPA 497, Recommended Practice for the Classification of Flammable Liquids, Gases, or Vapors and of Hazardous (Classified) Locations for ElectricalInstallations in Chemical Process Areas, 2012 edition.

NFPA 566, Bulk Oxygen Systems at Consumer Sites, 1965 edition.

NFPA 704, Standard System for the Identification of the Hazards of Materials for Emergency Response, 2012 edition.


NFPA 850, Recommended Practice for Fire Protection for Electric Generating Plants and High Voltage Direct Current Converter Stations, 2015 edition.


NFPA 5000 ®, Building Construction and Safety Code ®, 2015 edition.

M.1.2 Other Publications.

M.1.2.1 AMCA Publications.

Air Movement and Control Association, Inc., 30 West University Drive, Arlington Heights, IL 60004-1893.

AMCA 99, Standards Handbook 99-0401 , Classifications for Spark Resistant Construction , 2010.

M.1.2.2 ANSI Publications.


ANSI A13.1, Scheme for the Identification of Piping Systems , 2007.ANSI /AIHA Z9.5, Laboratory Ventilation, 2012.

ANSI/ASSE Z117.1, Safety Requirements for Confined Spaces, 2009.

ANSI/CSA FC 1, American National Standard for Fuel Cell Technologies- Part 3-100: Stationary Fuel Cell Power Systems - Safety , 2014.


ANSI/ISA 84.00.01, Application of Safety Instrumented Systems for the Process Industries, 2004.

ANSI B 40.1, Pressure Gauges and Gauge Attachments, 2005.

M.1.2.3 ASHRAE Publications.


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American Society of Heating, Refrigerating, and Air Conditioning Engineers, Inc., 1791 Tullie Circle, N.E., Atlanta, GA 30329-2305.

ASHRAE Handbook-Fundamentals, Chapter 24, “Airflow Around Buildings Buildings” , ” 2013.

ASHRAE 110 STD 110 , Method of Testing Performance of Laboratory Fume Hoods, 1995 2016 .

M.1.2.4 ASME Publications.

American Society of Mechanical Engineers ASME International , Two Park Avenue, New York, NY 10016-5990.

ASME A13.1, Scheme for the Identification of Piping Systems , 2015 .

ASME Boiler and Pressure Vessel Code, Section VIII, “Rules for Construction of Pressure Vessels,” Division 1, 2013 2015 .

ASME B31.1, Power Piping, 2012 2016 .

ANSI/ ASME B31.3, Process Piping, 2012 2016 .

ASME B31.12, Hydrogen piping and pipelines: ASME Code for Pressure Piping, B31, 2012 2014 .

Note: ASME Publications: B31.12-2012Hydrogen piping and pipelines: ASME Code for Pressure Piping, B31 is a use specific document for hydrogenservice. A Section Committee was formed by the B31 Standards Committee to address gaps that existed between piping and pipeline codes and standards,and hydrogen infrastructure applications. The first edition of the B31.12 code applies to design, construction, operation, and maintenance requirements forpiping, pipeline, and distribution in hydrogen service. ASME B31.12 includes information specific to hydrogen service by either reference or incorporation ofapplicable parts of B31.3, B31.1, B31.8, B31.8S, and Section VIII, Division 3 of the ASME Boiler and Pressure Vessel Code. Many materials included inB31.3 have been omitted from B31.12 tables due to their unsuitability for hydrogen service.

ASME B40.100 , Pressure Gauges and Gauge Attachments, 2013 .

M.1.2.5 ASTM Publications.

ASTM International, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959.

ASTM E1472, Standard Guide for Documenting Computer Software for Fire Models, 2005 (Withdrawn 2007) .

ASTM E2079, Standard Test Method for Limiting Oxygen (Oxidant) Concentration for Gases and Vapors, 2013.

M.1.2.6 CGA Publications.

Compressed Gas Association, 14501 George Carter Way, Suite 103, Chantilly, VA 20151-2923 1788 .

CGA Pamphlet P-1, Safe Handling of Compressed Gases in Containers, 8th 12 th edition, 2008 2015 .

CGA/ANSI V-1, Standard for Compressed Gas Cylinder Valve Outlet and Inlet Connections, 2013.

CGA H-5,Installation Standards Standard for Bulk Hydrogen Supply Systems, 2008 Edition 2015 .

M.1.2.7 U.S. Government Publications.

U.S. Government Printing Government Publishing Office, 732 North Capitol Street, NW, Washington, DC 20402 20401-0001 .

Title 16, Code of Federal Regulations, Part 1500.44.

Title 29, Code of Federal Regulations, Part 1910.

Title 40 Code of Federal Regulations, Part 260-299.

Title 49, Code of Federal Regulations, Part 173, Appendix H.


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M.1.2.8 Other Publications.

ACGIH Industrial Ventilation: A Manual of Recommended Practice, 2013 2016 .

“An Investigation of Chemical Fume Hood Fire Protection Using Sprinkler and Water Mist Nozzles,” Factory Mutual Research Corp., June, 1999.

API RP 579-1 , Recommended Practice for Fitness-for-Service, American Petroleum Institute, 1220 L St. NW, Washington, DC 20005. 2nd edition,2007, Errata, 2009 . (Supersedes API RP 579) (Same as ASME FFS-1)

API RP 2003, Protection Against Ignitions Rising Out of Static, Lightning, and Stray Currents , 8th edition, 2015 .

BS 7910, Guide To Methods For Assessing The Acceptability Of Flaws In Metallic Structures, British Standards Institution, 389 Chiswick High Rd., LondonW4 4AL, United Kingdom 13th edition, 2013, Corrigendum, 2015 .

BS EN 1081, Determination Resilient Floor Coverings — Determination of Electrical Resistance — Resilient Floor Coverings , 1998, reaffirmed 2010 .

Cryogenic Fluids in the Laboratory, NSC Data Sheet 1-688-86, National Safety Council, 1986.

Department of Energy, Environmental and Chemical Engineering, Washington University, St. Louis, MO 63130.

Department of Fire Protection Engineering, University of Maryland, College Park, MD 20742.

Frank-Kamenetskii, D. A. 1939. “Calculation of Thermal Explosion Limits.” U.S.S.R. Acta Physico-Chimica, Volume 10, p. 365.

Fuel cell technologies, Part 5-1; Portable fuel cell power systems—Safety, 2012.

Houf, W., and Schefer, R., Predicting Radiative Heat Fluxes and Flammability Envelopes from Unintended Releases of Hydrogen, Inter. Jour. of HydrogenEnergy 32: 136–151, 2007.

Houf, W., and Schefer, R., “Analytical and Experimental Investigation of Small-Scale Unintended Releases of Hydrogen,” Inter. Jour. of Hydrogen Energy33: 1435–1444, 2008.

Houf, W., Schefer, R. and Evans, G., Analysis of Barriers for Mitigation of Unintended Releases of Hydrogen, Paper presented at 2008 Annual HydrogenConference and Hydrogen Expo USA, March 30 – April 3, Sacramento, CA.

J. Floyd, “Siting Requirements for Hydrogen Supplies Serving Fuel Cell Power Systems in Non-Combustible Enclosures,” Jensen Hughes Associates ,Inc., 3610 Commerce Drive, Suite 817, Baltimore, MD 21227, HAI Project #3250-000, November 30, 2006. NFPA Fire Research Foundation, 2006.

LaChance, J., Philips, J., Houf, W., Risks Associated With the Use of Barriers in Hydrogen Refueling Stations, 2010.

M.S. Butlera, C.W. Moranb, P.B. Sunderlandb, R.L. Axelbauma, Limits for hydrogen leaks that can support stable flames, International Journal of HydrogenEnergy, 34 (2009) 5174-5182.

Pocket Guide to Chemical Hazards, NIOSH, National Institute for Occupational Safety and Health, September, 2005.

Procedure for Certifying Laboratory Fume Hoods to Meet EPA Standards, Environmental Protection Agency, Safety, Health, and EnvironmentalManagement Division (3207A), Ariel Rios Bldg., 1200 Pennsylvania Ave., NW, Washington, DC 20406. Atten: Chief, Technical Support and EvaluationBranch.

Schefer, R., Houf, W., Bourne, B., and Colton, J., “Spatial and Radiative Properties of an Open-Flame Hydrogen Plume,” Inter. Jour. of Hydrogen Energy31: 1332–1340, 2006.

Schefer, R., Houf, W., Williams, T.C., Bourne, B., and Colton, J., “Characterization of High-Pressure, Underexpanded Hydrogen-Jet Flames,” Inter. Jour. ofHydrogen Energy 32: 2081–2093, 2007.

Standard on Laboratory Fume Hoods (SEFA 1-2002), The Scientific Equipment and Furniture Association, 225 Reinekers, Suite 625, Alexandria, VA22314 65 Hilton Avenue , Garden City , NY 11530 .

U. S. Bureau of Mines Bulletin 627, Flammability Characteristics of Combustible Gases and Vapors, U.S. Bureau of Mines, Pittsburgh, PA, 1965.

M.2 Informational References.

The following documents or portions thereof are listed here as informational resources only. They are not a part of the requirements of this document.

M.2.1 NFPA Publications.


NFPA 59, Utility LP-Gas Plant Code, 2015 edition.


NFPA 1962, Standard for the Inspection, Care, and Use of Fire Hose, Couplings, and Nozzles and the Service Testing of Fire Hose, 2013 edition.

M.2.2 CGA Publications.


CGA G-6.1, Standard for Insulated Liquid Carbon Dioxide Systems at Consumer Sites, 2013.

CGA G-6.5, Standard for Small, Stationary, Insulated Carbon Dioxide Supply Systems, 2007 2013 .

CGA G-6.7, Safe Handling of Liquid Carbon Dioxide Containers That Have Lost Pressure2013 , 2009 .

CGA H. - 1, Conditions for Portable, Reversible Metal Hydride Systems, 2011.

CGA H-2, Guidelines for the Classification and Labeling of Hydrogen Storage Systems with Hydrogen Absorbed in Reversible Metal Hydrides, 2004.

M.2.3 ISO Publications.

International Organization for Codeization Publications, 1 rue de Varembé, Case Postale 56, CH-1211 Geneve 20, Standardization , ISO CentralSecretariat, Chemin de Blandonnet 8, CP 401, 1214 Vernier, Geneva , Switzerland.

ISO 10156, Gases and gas mixtures—Determination of Fire Potential and Oxidizing Ability for the Selection of Cylinder Valve Outlets, 2010, Corrigendum1, 2010 .

ISO 10298, Determination of Toxicity of a Gas or Gas Mixture, 2010.

ISO 22734-1, Hydrogen generators using water electrolysis process—Part 1: Industrial and commercial applications, 2011 2008 .

ISO 22734-2, Hydrogen generators using water electrolysis process—Part 2: Residential applications, 2011.


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ANSI Z21.21-2005 /CSA 6.5, Automatic Valves for Gas Appliances, 2005 2015 .

ANSI Z535.1, Safety Color Code, 2006 2011 .

ANSI/AIHA Z9.5, Laboratory Ventilation, 2012.

ANSI/UL 2085, Protected Aboveground Tanks for Flammable and Combustible Liquids, 1997, revised 1999 2003 .

ASTM D5/D5M , Standard Test Method for Penetration of Bituminous Materials, 2006 2013 .

ASTM D92, Standard Test Method for Flash and Fire Points by Cleveland Open Cup Tester , 2005 2012b .

ASTM D323, Standard Method of Test for Vapor Pressure of Petroleum Products (Reid Method), 2006 2015a .

ASTM E681-01 , Code Test Method for Concentration Limits of Flammability of Chemicals (Vapors and Gases), 2004 2009, reapproved 2015 .

CGA G-4.1, Cleaning Equipment for Oxygen Service, 2009.

CGA G-4.4, Piping Systems, 2012.


CGA G-6.5, Standard for Small, Stationary, Insulated Carbon Dioxide Supply Systems, 2013.

CGA H-1, Service Conditions for Portable, Reversible Metal Hydride Systems, 2011.


CGA P-23, Standard for Categorizing Gas Mixtures Containing Flammable and Nonflammable Components, 2008 2015 .

CGA Handbook of Compressed Gases, 5th Edition, 2013.

CRC Handbook of Laboratory Safety, Keith A. Furr, 5th edition, CRC Press, Chemical Rubber Company, Boca Raton, FL, 2000.

NSF /ANSI 49 49 , Biosafety Cabinetry: Design, Construction, Performance, and Field Certification, 2010 2014 .

UL 429, Standard for Electrically Operated Valves, 2009 2013 .

Allen, D. S. and P. Athens. 1968. “Influence of Explosion on Design.” Loss Prevention Manual — Volume 2. New York: American Institute of ChemicalEngineers.

Bader, M., C. C. Phillips, T. R. Mueller, W. S. Underwood, and S. D. Whitson. “Returning Perchlorate-Contaminated Fume Hood Systems to Service, Part II:Disassembly, Decontamination, Disposal, and Analytical Procedures.” Applied Occupational and Environmental Hygiene, Volume 14:369-375, 1999.

Brasie, W. C. and D. W. Simpson. 1968. “Guidelines for Estimating Explosion Damage.” Loss Prevention Manual — Volume 2. New York. American Instituteof Chemical Engineers.

Brinkley, S. R. 1969. “Determination of Explosion Yields.” Loss Prevention Manual — Volume 3. New York: American Institute of Chemical Engineers.

Cohen, E. 1968. “Prevention of and Protection Against Accidental Explosion of Munitions, Fuels, and Other Hazardous Mixtures.” New York Academy ofScience Annals — Volume 152. New York: New York Academy of Science.

Cote, A. E. Fire Protection Handbook, 20th edition. Quincy, MA: National Fire Protection Association.

Damon, E. G. et al. 1971. Biodynamics of Air Blast, Albuquerque, NM: Lovelace Biomedical and Environmental Research Institute.

Dobbs, N. et al. 1970. New Concepts in the Design of Structures to Resist the Effects of Explosive-Toxic Detonations. Dover, NJ: Picatinny Arsenal.

Floyd, J., “Siting Requirements for Hydrogen Supplies Serving Fuel Cells in Non-Combustible Enclosures" , “Hughes Associates, Inc., Jensen Hughes,3610 Commerce Drive, Suite 817, Baltimore, MD 21227, HAI Project #3250-000, November 30, 2006. Fire Protection Research Foundation, 2006.

Gray, P. and P. R. Lee. Thermal Explosion Theory, New York: Elsevier Publishing Co.

Hartwigsen, C. 1971. Shrapnel Containment Shields. Albuquerque, NM: Sandia Laboratories.

Houf, W., and R. Schefer, “Analytical and Experimental Investigation of Small-Scale Unintended Releases of Hydrogen,” Inter. J. Hydrogen Energy33:1435-1444, 2008.

Houf, W., and R. Schefer, “Predicting Radiative Heat Fluxes and Flammability Envelopes from Unintended Releases of Hydrogen,” Inter. J. HydrogenEnergy, 32:136–151, 2007.

Industrial Ventilation: A Manual of Recommended Practice for Operation and Maintenance, 26th edition. 2007. Lansing, MI: American Conference ofGovernmental Industrial Hygienists.

JANNAF Propulsion Committee. 1971. “Chemical Propellant/Rocket Hazards.” General Safety Engineering Design Criteria, Volume 2. Silver Springs, MD:Chemical Propulsion Information Agency.

Johnson, W. G. 1973. The Management Oversight and Risk Tree. Washington, DC: U.S. Government Printing Government Publishing Office.

Kinney, G. F. 1986. Explosive Shocks in Air. New York: The Macmillan Co.

Kinney, G. F. and G. S. Robert. 1972. Pressure Rises in Internal Explosions. Albuquerque, NM: University of New Mexico.

LaChance, J., W. Houf, B. Middleton (all of Sandia National Laboratories), and L. Fluer (of Fluer, Inc.), “Analyses to Support Development of Risk-InformedSeparation Distances for NFPA Hydrogen Codes and Standrds,” SAND 2009-0874, Sandia National Laboratories, Albuquerque, NM 87185, andLovermore, CA 94550, March 2009.

LaChance, J., W. Houf, R. Schefer, and G. Evans, “Analysis of Bariers for Mitigation of Unintended Releases of Hydrogen,” Paper presented at AnnualHydrogen Conference and Hydrogen Expo USA, March 30-April 3, 2008, Sacramento, CA.

Lawrence, W. E. and E. E. Johnson. 1974. “Design for Limiting Explosion Damage.” Chemical Engineering, Volume 81, No. 1, pp. 96–104.

Lewis, B. and von Elbe, G., Combustion, Flames, and Explosions of Gases, Academic Press, 2nd Edition, New York 1961.

Manual of Tests and Criteria, 4th edition.

Matheson Gas Data Book, 7th edition, Matheson Co., East Rutherford, NJ, 2001.

Newmark, N. M. 1956. “An Engineering Approach to Blast Resistant Design.” American Society of Civil Engineers, Transaction 121.

“NIOSH Alert: Preventing Worker Injuries and Deaths from Explosions in Industrial Ethylene Oxide Sterilization Facilities.” Available at www.cdc.gov/niosh/homepage.html.

Norris, C. H. et al. 1959. Structural Design for Dynamic Loads. New York: McGraw-Hill.

Phillips, C. C., T. R. Mueller, B. Marwan, M. W. Haskew, J. B. Phillips, and D. O. Vick. “Returning Perchlorate-Contaminated Fume Hood Systems toService, Part I: Survey, Sampling, and Analysis.” Applied Occupational and Environmental Hygiene, 9(7):503-509, July 1994.


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Polentz, L. M. “The Peril in Pressurized Liquids.” Design News, September 6 and October 22, 1973.

Prudent Practices in the Laboratory, National Research Council, National Academy Press, Washington DC, 1995.

Rogers, R. N. and J. Zinn. 1962. “Thermal Initiation of Explosives.” Journal of Physical Chemistry, Volume 66, p. 2646.

Rules of the City of New York, “Chemical Laboratories,” Chapter 10. 1991. Albany, NY: Lenz & Rieker, Inc.

Schefer, R., W. Houf, B. Bournd, and J. Colton, “Spatial and Radiative Properties of an Open-Flame Hydrogen Plume,” Inter.J. Hydrogen Energy31:1332-1340,2006.

Schefer R., W. Houf, T.C. Williams, B. Bourne, and J. Colton, “Characterization of High-Pressure, Underexpanded Hydrogen Jet Flames,” Inter. J. HydrogenEnergy 32:2081-2093, 12007.

Schilt, Alfred A., 1979. Perchloric Acid and Perchlorates. Columbus, OH: The G. Frederick Smith Chemical Company.

Scott Specialty Gases, Design and Safety Handbook, 2007 edition.

Smith, L. C. and M. J. Urizar. 1967. Lightweight Safety Shields for Small Scale Operations Involving Explosives. Los Alamos, NM: Los Alamos ScientificLaboratories.

Tanaka, T., Azuma, T., Evans, J., Cronin, P., Johnson, D., and Cleaver, R./ “Experimental Study on Hydrogen Explosions in a Full-Scale Hydrogen FillingStation Model,” International Conference on Hydrogen Safety, Pisa Italy 8–10 September 2005.

Standard Specification for Laboratory Fume Hoods, Environmental Protection Agency, Washington, DC 20460, Attn: Chief, Facilities Engineering and RealProperty Branch (PM-215).

UN Recommendations on the Transport of Dangerous Goods, 15 1 9 th Revised Edition.

UN Recommendations on the Transit the Transport of Dangerous Goods, Model Regulations, 15 th edition 19 t h revised edition .


Uniform Mechanical Code, 2003 2018 edition.

M.3 References for Extracts in Informational Sections.







NFPA 56, Standard for Fire and Explosion Prevention During Cleaning and Purging of Flammable Gas Piping Systems, 2014 edition.




NFPA 72 ®, National Fire Alarm and Signaling Code, 2016 edition.










Public Input No. 4-NFPA 2-2016 [Chapter 2] Referenced current SDO names, addresses, standard names, numbers, and editions.




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Submittal Date: Sat Jan 30 23:01:22 EST 2016


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Public Input No. 72-NFPA 2-2016 [ Section No. M.1.2.2 ]

M.1.2.2 ANSI Publications.


ANSI A13.1, Scheme for the Identification of Piping Systems, 2007.


ANSI/ASSE Z117.1, Safety Requirements for Confined Spaces,2009.

ANSI/CSA FC 1, American National Standard for Fuel Cell Power Systems, 2014.


ANSI/ ISA 84.00.01, Application of Safety Instrumented Systems for the Process Industries, 2004.

ANSI B 40.1, Pressure Gauges and Gauge Attachments,2005.


Remove CSA Group Reference Publications from M.1.2.2 ANSI Publications. Proposal to recognize CSA Group as publisher of FC 1 & FC 3 has been submitted separately.



Public Input No. 73-NFPA 2-2016 [New Section after M.1.2.6]




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City:

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Public Input No. 54-NFPA 2-2016 [ Section No. M.1.2.5 ]

M.1.2.5 ASTM Publications.

ASTM International, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959.

ASTM E1472, Standard Guide for Documenting Computer Software for Fire Models, 2005 2007 (withdrawn 2011) .

ASTM E2079, Standard Test Method for Limiting Oxygen (Oxidant) Concentration for Gases and Vapors, 2007 ( 2013) .


updates




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City:

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Submittal Date: Sun May 15 17:18:48 EDT 2016


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Public Input No. 73-NFPA 2-2016 [ New Section after M.1.2.6 ]

M.1.2.7 CSA Group Publications. CSA Group, 8501 East Pleasant Valley Road, Cleveland, OH 44131.

ANSI/CSA FC 1, Fuel cell technologies — Part 3-100: Stationary fuel cell power systems – Safety, 2014.

ANSI/CSA America FC 3, Standard For Portable Fuel Cell Power Systems, 2004.

ANSI/CSA HGV 4.1, Standard for hydrogen dispensing systems, 2013.

ANSI/CSA HGV 4.2, Standard for hoses for compressed hydrogen fuel stations, dispensers and vehicle fuel systems, 2013.

ANSI/CSA HGV 4.3, Test methods for hydrogen fueling parameter evaluation, 2016.

ANSI/CSA HGV 4.4, Standard for breakaway devices for compressed hydrogen dispensing hoses and systems, 2013.

ANSI/CSA HGV 4.6, Manually operated valves for use in gaseous hydrogen vehicle fueling stations, 2013.

ANSI/CSA HGV 4.7, Automatic valves for use in gaseous hydrogen vehicle fueling stations, 2013.

ANSI/CSA HGV 4.8, Hydrogen gas vehicle fueling station compressor guidelines, 2012.

ANSI/CSA HGV 4.10, Standard For Fittings for compressed hydrogen gas and hydrogen rich gas mixtures, 2012.


Move CSA FC 1 & FC 3 from M.1.2.2 ANSI Publications to a new section to recognize CSA Group as publisher of these documents. This proposal also updates CSA document designations, tiles and/or year of edition. Additional reference standards that were proposed to be added to A.10.3.1.1 are being added to this new clause as well.



Public Input No. 72-NFPA 2-2016 [SectionNo. M.1.2.2]

PI #72 removes CSA Group Standards from M.1.2.2 ANSI Publications. PI #73 proposes to create a newsection for CSA Group publications.

Public Input No. 68-NFPA 2-2016 [SectionNo. A.10.3.1.1]

Public Input No. 311-NFPA 2-2016 [SectionNo. 10.3.1.1]




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Public Input No. 75-NFPA 2-2016 [ New Section after M.2.2 ]

CSA Group Publications. CSA Group, 8501 East Pleasant Valley Road, Cleveland, OH 44131

ANSI/CSA CHMC 1, Test methods for evaluating material compatibility in compressed hydrogen applications - Metals, 2014.

ANSI/CSA HGV 4.5, Standard for priority and sequencing equipment for hydrogen vehicle fueling, 2013.

ANSI Z21.21 • CSA 6.5, Automatic valves for gas appliances, 2015.

CSA HGV 4.9, Hydrogen fueling stations, 2016.


Move CSA Group document ANSI Z21.21 • CSA 6.5 from M.2.4 Other Publications section to a new section to recognize CSA Group as publisher of this document. This proposal also updates the document year of edition. Other CSA Group documents (CSA CHMC 1, CSA HGV 4.5 and CSA HGV 4.9) are included in this proposal to provide additional Informational References.



Public Input No. 74-NFPA 2-2016 [SectionNo. M.2.4]

PI #74 removes CSA Group Standards from M.2.4 Other Publications. PI #75 proposes to create a new sectionfor CSA Group publications.




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Public Input No. 258-NFPA 2-2016 [ Section No. M.2.4 ]


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ANSI Z21.21-2005/CSA 6.5, Automatic Valves for Gas Appliances, 2005.

ANSI Z535.1, Safety Color Code, 2006.


ANSI/UL 2085, Protected Aboveground Tanks for Flammable and Combustible Liquids, 1997, revised 1999.

ASTM D5, Standard Test Method for Penetration of Bituminous Materials, 2006.

ASTM D92, Standard Test Method for Flash and Fire Points by Cleveland Open Cup, 2005.

ASTM D323, Standard Method of Test for Vapor Pressure of Petroleum Products (Reid Method), 2006.

ASTM E681-01, Code Test Method for Concentration Limits of Flammability of Chemicals (Vapors and Gases), 2004.







CGA P-23, Standard for Categorizing Gas Mixtures Containing Flammable and Nonflammable Components, 2008.



NSF/ANSI 49, Biosafety Cabinetry: Design, Construction, Performance, and Field Certification, 2010.

UL 429, Standard for Electrically Operated Valves, 2009 2013 .









Floyd, J., “Siting Requirements for Hydrogen Supplies Serving Fuel Cells in Non-Combustible Enclosures, “Hughes Associates, Inc., 3610 CommerceDrive, Suite 817, Baltimore, MD 21227, HAI Project #3250-000, November 30, 2006. Fire Protection Research Foundation, 2006.







Johnson, W. G. 1973. The Management Oversight and Risk Tree. Washington, DC: U.S. Government Printing Office.














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UN Recommendations on the Transport of Dangerous Goods, 15th Revised Edition.

UN Recommendations on the Transit of Dangerous Goods, Model Regulations, 15th edition.


Uniform Mechanical Code, 2003 edition.


This modification updates the referenced UL Standard to the most recent edition.




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Public Input No. 74-NFPA 2-2016 [ Section No. M.2.4 ]


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ANSI Z21.21-2005/CSA 6.5, Automatic Valves for Gas Appliances , 2005.ANSI Z535.1, Safety Color Code, 2006.


ANSI/UL 2085, Protected Aboveground Tanks for Flammable and Combustible Liquids, 1997, revised 1999.

ASTM D5, Standard Test Method for Penetration of Bituminous Materials, 2006.

ASTM D92, Standard Test Method for Flash and Fire Points by Cleveland Open Cup, 2005.

ASTM D323, Standard Method of Test for Vapor Pressure of Petroleum Products (Reid Method), 2006.

ASTM E681-01, Code Test Method for Concentration Limits of Flammability of Chemicals (Vapors and Gases), 2004.







CGA P-23, Standard for Categorizing Gas Mixtures Containing Flammable and Nonflammable Components, 2008.



NSF/ANSI 49, Biosafety Cabinetry: Design, Construction, Performance, and Field Certification, 2010.

UL 429, Standard for Electrically Operated Valves, 2009.









Floyd, J., “Siting Requirements for Hydrogen Supplies Serving Fuel Cells in Non-Combustible Enclosures, “Hughes Associates, Inc., 3610 CommerceDrive, Suite 817, Baltimore, MD 21227, HAI Project #3250-000, November 30, 2006. Fire Protection Research Foundation, 2006.







Johnson, W. G. 1973. The Management Oversight and Risk Tree. Washington, DC: U.S. Government Printing Office.














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UN Recommendations on the Transport of Dangerous Goods, 15th Revised Edition.

UN Recommendations on the Transit of Dangerous Goods, Model Regulations, 15th edition.


Uniform Mechanical Code, 2003 edition.


Remove CSA Group Reference Publication from M.2.4 Other Publications. Proposal to recognize CSA Group as publisher of ANSI Z21.21 • CSA 6.5 has been submitted separately.



Public Input No. 75-NFPA 2-2016 [New Section after M.2.2]




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Public Input No. 91-NFPA 55-2016 [ Global Input ]

Add chapter 17 as shown:

Chapter 17 – Cryogenic Fluid Central Supply Systems for Health Care Facilities

17.1 General.

17.1.1* The storage, use, and handling of cryogenic fluid central supply systems that delivercompressed medical gases (CMG) to health care facilities shall be in accordance with theprovisions of this chapter and Chapters 1 through 16 as applicable.

A.17.1.1 The cryogenic fluid central supply system should be installed on a site that has beenprepared to meet the requirements of NFPA 55. A storage unit(s), reserve, pressure regulation, anda signal actuating switch(es) are components of the supply system. Shutoff valves, piping from thesite, and electric wiring from a signal switch(es) to the master signal panels are components of thepiping system.

The cryogenic fluid central supply system is normally installed on the site by the owner of thisequipment. The owner or the organization responsible for the operation and maintenance of thebulk supply system is responsible for ensuring that all components of the supply system — mainsupply, reserve supply, supply system signal-actuating switch(es), and delivery pressure regulationequipment — function properly before the system is put in service.

17.1.2 Applicability

17.1.2.1 The source valve shall be the line separating the applicability of NFPA 55 and NFPA 99.

17.1.2.2 Cryogenic fluid central supply system installations up to, but not including, the sourcevalve shall be covered by NFPA 55.

17.1.2.3 The source valve and all downstream piping and components, including wiring to storagesystem alarms, shall be covered by NFPA 99.

17.2 Cryogenic fluid central supply systems installation

17.2.1 Cryogenic fluid central supply systems shall be installed by personnel qualified inaccordance with ANSI/CGA M-1, Standard for Medical Gas Supply Systems at Health Care Facilities,or ASSE 6015, Professional Qualification Standard for Bulk Medical Gas Systems Installers.

17.2.2 Cryogenic fluid central supply systems shall be installed in compliance with Food andDrug Administration Current Good Manufacturing Practices as found in 21 CFR 210 and 21 CFR 211.

17.2.3 Cryogenic fluid central supply systems shall be anchored with foundations in accordancewith the provisions of ANSI/CGA M-1, Standard for Medical Gas Supply Systems at Health CareFacilities.

17.2.4 Cryogenic fluid central supply systems shall have a minimum work space clearance of 3ft (1 m) around the storage container, vaporizer(s), and the cabinet opening or front side of thepressure regulating manifold for system maintenance and operation.

17.2.5 Inert cryogenic fluid central supply systems shall be sited in accordance with chapter 8and CGA P-18, Standard for Bulk Inert Gas Systems.

17.2.6 Oxygen cryogenic fluid central supply systems shall be sited in accordance with chapters8 and 9 as applicable and in accordance with CGA M-1, Standard for Medical Gas Supply Systemsat Health Care Facilities.

17.2.7 Carbon dioxide cryogenic fluid central supply systems shall be sited in accordance withchapter 13 and CGA G-6.1, Standard for Insulated Liquid Carbon Dioxide Systems at ConsumerSites.

17.2.8 Nitrous oxide cryogenic fluid central supply systems shall be sited in accordance withchapter 16 and CGA G-8.1, Standard for Nitrous Oxide Systems at Customer Sites.

17.3 Cryogenic fluid central supply systems system operation


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17.3.1 The following components of the cryogenic fluid central supply system shall be accessibleand visible to delivery personnel during filling operations:

(1) Fill connection

(2) Top and bottom fill valves

(3) Hose purge valve

(4) Vent valve

(5) Full trycock valve

(6) Liquid level gauge

17.3.2 C ryogenic fluid central supply systems shall consist of the following:

(1) One or more main supply vessel(s), whose capacity shall be determined after consideration ofthe customer usage requirements, delivery schedules, proximity of the facility to alternativesupplies, and the emergency plan

(2) A contents gauge on each of the main vessel(s)

(3) A reserve supply sized for greater than an average day's supply, with the size of vessel ornumber of cylinders being determined after consideration of delivery schedules, proximity of thefacility to alternative supplies, and the facility's emergency plan

(4) At least two main vessel relief valves and rupture discs installed downstream of a three-way(three-port) valve

(5) A check valve located in the primary supply piping upstream of the intersection with asecondary supply or reserve supply

17.3.3 R eserve CMG supply systems consisting of either a second cryogenic fluid source or acompressed gas source shall include the following:

(1) When the reserve source is a compressed gas source, the reserve shall be equipped with thefollowing:

(a) A cylinder manifold having not less than three gas cylinder connections or as otherwiserequired for an average of one day's gas supply

(b) A pressure switch to monitor the pressure in the cylinder manifold

(2) When the reserve source is a second cryogenic fluid vessel, the reserve tank shall be equippedwith the following:

(a) An actuating switch or sensor to monitor the internal tank pressure

(b) A contents gauge to monitor the liquid level

(3) When the reserve source is either a cryogenic fluid or compressed gas source, a check valveshall be provided to prevent backflow into the reserve system

17.3.4 Bulk cryogenic liquid sources shall include automatic means to provide the followingfunctions:

(1) When the main supply is supplying the system, the reserve supply shall be prevented fromsupplying the system until the main supply is reduced to a level at or below the reserve activationpressure.

(2) When the main supply cannot supply the system, the reserve supply shall automatically beginto supply the system.

(3) Where there is more than one main supply vessel, the system shall operate as described belowfor primary, secondary, and reserve operation:

a) If provided with two liquid container headers, one cryogenic liquid header shall be theprimary and the other shall be the secondary, with either being capable of either role.

b) If provided with one liquid container header and one gas cylinder header (a hybridarrangement), the liquid container header is the primary and the gas cylinder header is thesecondary.

c) When the primary header is supplying the system, the secondary header is preventedfrom supplying the system.

d) When the primary header is depleted, the secondary header automatically begins to


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supply the system.

(4) Where there are two or more cryogenic vessels, they shall be permitted to alternate (e.g., on atimed basis) in the roles of primary, secondary, and reserve, provided that an operating cascade(primary–secondary–reserve) is maintained at all times.

(5) Where a cryogenic vessel is used as the reserve, the reserve vessel shall include a means toconserve the gas produced by evaporation of the cryogenic liquid in the reserve vessel and todischarge the gas into the line upstream of the final line regulator assembly.

17.4 Main supply system

17.4.1 The main supply vessel for a cryogenic fluid central supply system shall be a cryogenicstorage tank.

17.5 Reserve supply system

17.5.1 A CMG reserve supply system shall consist of the following:

(1) A secondary cryogenic vessel or

(2) A high pressure compressed gas source.

17.5.2 A cryogenic source reserve supply shall have a switch or sensor to monitor the tankpressure.

17.5.3 A compressed gas reserve supply shall meet the following requirements:

17.5.3.1 It shall be manifolded with no fewer than three gas cylinders.

17.5.3.2 It shall have a pressure switch or sensor to monitor the contents using manifoldpressure.

17.5.3.3 It shall have a check valve to prevent backflow into the system.

17.5.3.4 It shall have a check valve at each connection on the cylinder header to minimizeloss of gas from the reserve system.

17.6 Cryogenic fill system

17.6.1 A cryogenic fluid central supply system shall have a fill system consisting of the following:

(1) A non-removable product specific fill connection in compliance with CGA V-6 StandardCryogenic Liquid Transfer Connection or CGA V-1, Standard for Compressed Gas Cylinder ValveOutlet and Inlet Connections

(2) A method to cap and secure the fill connection inlet

(3) A check valve to prevent product flow from the CMG supply system

(4) A fill hose purge valve

(5) Supports to hold the fill piping off the ground

(6) Supports to hold the fill line in position during all filling operations

17.7 Cryogenic fluid central supply systems shall include a fill mechanism consisting of thefollowing components:

(1) A nonremovable product-specific fill connection in compliance with CGA V-6, StandardCryogenic Liquid Transfer Connection

(2) A means to cap and secure the fill connection inlet

(3) A check valve to prevent product backflow from the fill inlet


5) Supports that hold the fill piping off the ground

(6) A secure connection between the bulk tank and the fill piping

(7) Supports as necessary to hold the fill line in position during all operations associatedwith the filling procedure

17.7 Vaporizers

17.7.1 Where vaporizers are used to convert cryogenic CMG to a gaseous state they shall meet thefollowing requirements.

17.7.1.1 Vaporizers shall be permitted to operate by either ambient heat transfer or


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external thermal source (e.g. electric heater, hot water, steam).

17.7.1.2 Vaporizers using a heat source other than ambient air shall be protected in theevent of a loss of the energy source.

17.7.2 Vaporizers shall be designed to provide capacity for the customer’s use under the followingconditions:

(1) Customer’s average and peak flows

(2) Local conditions, (e.g., structure that obstruct air circulation and/or sunlight)

(3) Seasonal conditions (e.g., freeze periods)

17.7.3 A system design that uses switching vaporizers shall meet all of the followingprovisions:

(1) Valves shall be permitted to be manual or automatic.

(2) Valves and piping shall allow an operating vaporizer or an operating section of avaporizer to be switched to a non-operating condition for de-icing.

(3) The system design shall provide continuous flow of CMG to the health care facilityduring vaporizer switch-over.

(4) The system design shall provide continuous flow of CMG to the health care facility ifvaporizer switch-over fails.

17.7.4 Where a vaporizer uses an external thermal source, the flow of the CMG shall be unaffectedby the loss of the external thermal source by one of the following methods:

(1) Reserve ambient heat transfer vaporizers sized for at least one day’s averagesupply and piped so that the flow of the CMG is unaffected by flow stoppage throughthe external thermal source vaporizer.

(2) A non-cryogenic source capable of providing at least one day’s average supply.

17.7.5 Where the reserve system use vaporizers they shall:

(1) Be sized by the supplier to provide a source of vaporized CMG from the reservebulk liquid storage vessel during times when the reserve system is operational

(3) Provide a flow rate equal to at least that of the main system vaporizer(s)however, the duration of flow may be different

(4) Be indirectly heated by ambient air

17.7.6 Low temperature protection systems that interrupt or reduce flow shall not be used on thereserve of cryogenic fluid central supply systems.

17.8 High pressure manifolds

17.8.1 Manifold assemblies shall be fit for service and shall have supports that are independent ofthe cylinders.

17.8.2 Cylinders on the manifold shall be secured against movement.

17.8.3* Cylinders on the manifold shall have the same service pressure rating or the filled pressureof each cylinder shall not exceed the service pressure rating of the lowest rated cylinder on themanifold.

A.17.8.3 For example, 2400 psi (16 550 kPa) rated cylinders are not connected to the same manifoldas 2015 psi (13 890 kPa) rated cylinders unless all cylinders, including the 2400 psi cylinders, arefilled no higher than 2015 psi (13 890 kPa).

17.9 Pressure control devices

17.9.1 The final pressure control device assembly or assemblies shall not be fabricated on site.

17.10 Pressure relief devices

17.10.1 Pressure relief devices (PRDs) shall meet the following requirements:

17.10.1.1 PRDs shall have a relief pressure setting not higher than the maximum allowable workingpressure (MAWP) of the component with the lowest working pressure rating in the portion of thesystem being protected.

17.10.1.2 PRDs shall be of brass, or bronze, construction.


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17.10.1.3 PRDs shall be designed for the specific gas service.

17.10.1.4 PRDs shall have the discharge turned down to prevent the entry of rain orsnow.

17.10.1.5 PRDs shall be designed in accordance with ASME B31.3, PressureProcess Piping.

17.10.2 PRDs shall have an identifier that contains the date of manufacture or test.

17.10.2 The final line pressure relief valves shall be approved by a nationally recognizedorganization and shall have a relief capacity greater than or equal to the maximumthroughput of the final line regulator.

17.10.2.1 The pressure relief valve shall be set at 50% above the normal workingpressure, but no higher than the MAWP, of the health care facility pipeline.

17.10.2.2 The relief valve information shall be stamped either on the nameplate of therelief valve or on a permanently attached metal tag.

17.11 Tubing and valves

17.11.1 New, hard drawn Type K or L copper tube shall be used for all process piping.

17.11.1.1 Tubing shall comply with ASTM B819, Standard Specification for Seamless Copper Tubefor Medical Gas Systems.

17.11.1.2 Tubing shall be capped and bear the marking OXY or MEDICAL or be otherwise packagedand labeled to indicate it is clean for oxygen service according to the supplier’s policy.

17.11.2 Instrumentation tubing shall be constructed of annealed copper tubing or seamlessstainless steel tubing.

17.11.2.1 Copper tubing shall comply with ASTM B88, Standard Specification for Seamless CopperWater Tube.

17.11.3 Valves of quick open or quarter-turn designs such as ball or plug valves shall not bepermitted in the high pressure portion of an oxygen piping system.

17.11.4* Alternate materials of construction for piping, tubing, valves, and instruments shall bepermitted for installation at the request of the health care facility or the supplier.

A.17.11.4 A typical alternate material is stainless steel.

17.11.4.1 Technical documentation shall be submitted to the health care facility QA representative todemonstrate equivalency.

17.12 Alarms

17.12.1* The cryogenic fluid central supply system shall have a local signal that visibly indicates theoperating status of the equipment and an indicator at all master alarms under the followingconditions:

1. When or at a predetermined set point before the main supply reaches an average day'ssupply, indicating low contents

2. When or at a predetermined set point before the reserve supply begins to supply thesystem, indicating reserve is in use

3. When or at a predetermined set point before the reserve supply contents fall to oneday's average supply, indicating reserve low

4. If the reserve is a cryogenic vessel, when or at a predetermined set point before thereserve internal pressure falls too low for the reserve to operate properly, indicatingreserve failure

5. Where there is more than one main supply vessel, when or at a predetermined setpoint before the secondary vessel begins to supply the system, indicating changeover

A.17.12.1

The local signal arose from the simple need of a maintenance person to know what is going onwith any given piece of source equipment. Note that it is not an alarm in the sense of a local ormaster alarm. It is simply an indicator, which might be a gauge, a flag, a light, or some otherpossible manifestation that allows a maintenance person to stand at the equipment and knowwhat conditions are present (e.g., which header of cylinders is in service). The elements to be


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displayed are typically those that will also be monitored at the master alarm, but the local signalis visible at the equipment rather than remotely.


Bulk supply system requirements are being moved from NFPA 99 to NFPA 55 to have storage system requirements for all compressed gas and cryogenic fluid systems in one document for ease of use. NFPA 99 will use the NFPA extract method to copy specific bulk medical gas supply system requirements.



Public Input No. 90-NFPA 55-2016 [Section No. 8.5]



Submitter Full Name: Jonathan Willard

Organization: Acute Medical Gas Services

Street Address:

City:

State:

Zip:



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1.1.2 Specific Applications.

This code shall not apply to the following:

(1)

(2) Storage, use, and handling of radioactive gases in accordance with NFPA 801

(3)

(4) Systems consisting of cylinders of oxygen and cylinders of fuel gas used for welding and cutting inaccordance with NFPA 51

(5)

(6)

(7) Storage, use, and handling of liquefied petroleum gases in accordance with NFPA 58

(8) Storage, use, and handling of compressed gases within closed-cycle refrigeration systems complyingwith the mechanical code

(9) Liquefied natural gas (LNG) storage at utility plants under NFPA 59A

(10) Compressed natural gas (CNG) and liquefied natural gas (LNG) utilized as a vehicle fuel inaccordance with NFPA 52

(11)

(12) Nonflammable mixtures of ethylene oxide with other chemicals

(13) Ethylene oxide in chambers 10 scf (0.283 Nm3) or less in volume or for containers holding 7.05 oz(200 g) of ethylene oxide or less


The NFPA 99/55 Task Group is proposing a new chapter for Cryogenic Fluid Central Supply Systems for Health Care Facilities. This change is to clarify the specific applications of NFPA 55.



Public Input No. 35-NFPA 55-2016 [Section No. A.1.1.2(3)]




Street Address:

City:

State:

Zip:


* Off-site transportation of materials covered by this code

* Use and handling of medical compressed gases at health care facilities in accordance withNFPA 99, except as specified in Chapter 17

* Flammable gases used as a vehicle fuel when stored on a vehicle.

* Storage, use, and handling of liquefied and nonliquefied compressed gases in laboratory work areasin accordance with NFPA 45

* Compressed hydrogen gas (GH2), or liquefied hydrogen gas (LH2) generated, installed, stored,

piped, used, or handled in accordance with NFPA 2 when there are no specific or applicablerequirements in NFPA 55


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Chapter 2 Referenced Publications

2.1 General.

The documents or portions thereof listed in this chapter are referenced within this code and shall beconsidered part of the requirements of this document.

2.2 NFPA Publications.



NFPA 2, Hydrogen Technologies Code , 2016 edition.

NFPA 10, Standard for Portable Fire Extinguishers, 2013 edition.


NFPA 16, Standard for the Installation of Foam-Water Sprinkler and Foam-Water Spray Systems, 2015edition.



NFPA 51, Standard for the Design and Installation of Oxygen–Fuel Gas Systems for Welding, Cutting, andAllied Processes, 2013 edition.



NFPA 59A, Standard for the Production, Storage, and Handling of Liquefied Natural Gas (LNG), 2013edition.




NFPA 72® , National Fire Alarm and Signaling Code, 2016 edition.

NFPA 99, Health Care Facilities Code, 2015 edition.

NFPA 110, Standard for Emergency and Standby Power Systems, 2016 edition.


NFPA 496, Standard for Purged and Pressurized Enclosures for Electrical Equipment, 2013 edition.

NFPA 505, Fire Safety Standard for Powered Industrial Trucks Including Type Designations, Areas of Use,Conversions, Maintenance, and Operations, 2013 edition.

NFPA 704, Standard System for the Identification of the Hazards of Materials for Emergency Response,2012 edition.


2.3 Other Publications.


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2.3.1 ASME Publications.

American Society of Mechanical Engineers ASME International , Two Park Avenue, New York, NY10016-5990.



ASME B31.12, Hydrogen Piping and Pipelines, 2011 2014 .

Boiler and Pressure Vessel Code, “Rules for the Construction of Unfired Pressure Vessels,” Section VIII,2013 2015 .

2.3.2 ASSE Publications.

American Society of Sanitary Engineering, 901 Canterbury Road, Suite A, Westlake, OH44145-1480 ASSE International , 18927 Hickory Creek Drive , Suite 220 , Mokena , IL 60448 .

ASSE/IAMPO/ANSI 6015, Professional Qualification Standard for Bulk Medical Gas Systems Installers,2012 2015 .


ASTM International, 100 Barr Harbor Drive, P.O. Box C700, West Conshohocken, PA 19428-2959.

ASTM E84, Standard Test Method for Surface Burning Characteristics of Building Materials, 2014 2015b.

ASTM E136, Standard Test Method for Behavior of Materials in a Vertical Tube Furnace at 750°C, 20122016 .

ASTM E681, Standard Test Method for Concentration Limits of Flammability of Chemicals (Vapors andGases), 2009, reapproved 2015 .

ASTM E1529, Standard Test Methods for Determining Effects of Large Hydrocarbon Pool Fires onStructural Members and Assemblies, 2013 2014a .

ASTM E2652, Standard Test Method for Behavior of Materials in a Tube Furnace with a Cone-ShapedAirflow Stabilizer, at 750 Degrees C, 2012 2016 .

2.3.4 CGA Publications.

Compressed Gas Association, 14501 George Carter Way, Suite 103, Chantilly, VA 20151-2923.

CGA C-7, Guide to Preparation of Precautionary Labeling and Marking of Compressed Gas Containers,2011 Classification and Labelling of Compressed Gases 2014 .


CGA G-4.10, Design Considerations to Mitigate the Potential Risks of Toxicity When Using NonmetallicMaterials in High Pressure Oxygen Breathing Gas Systems, 2008.

CGA G-5.5, Hydrogen Vent Systems, 2014.

ANSI/CGA G-13, Storage and Handling of Silane and Silane Mixtures, 2006 2015 .

CGA M-1, Standard for Medical Gas Supply Systems at Health Care Facilities, 2013.

CGA P-1, Safe Handling of Compressed Gases in Containers, 2008 2015 .

ANSI/CGA P-18, Standard for Bulk Inert Gas Systems at Consumer Sites, 2013.

CGA P-20, Standard for the Classification of Toxic Gas Mixtures, 2009.

CGA P-23, Standard for Categorizing Gas Mixtures Containing Flammable and NonflammableComponents, 2008 2015 .

CGA S-1.1, Pressure Relief Device Standards – Part 1 – Cylinders for Compressed Gases, 2011.

CGA S-1.2, Pressure Relief Device Standards – Part 2 – Portable Containers for Compressed Gases,2009.

CGA S-1.3, Pressure Relief Device Standards – Part 3 – Stationary Storage Containers for CompressedGases, 2008.

CGA V-6, Standard Bulk Refrigerated Liquid Transfer Connections, 2008 2014 .


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2.3.5 * CTA Publications.

Canadian Transportation Agency, Queen's Printer, Ottawa, Ontario, Canada. (Available from the CanadianCommunications Group Publication Centre, Ordering Department, Ottawa, Canada K1A 0S9.)

Transportation of Dangerous Goods Regulations.

2.3.6 IAPMO Publications.

International Association of Plumbing and Mechanical Officials, 4755 E. Philadelphia Street, Ontario, CA91761.

Uniform Mechanical Code, 2012 2015 edition.

2.3.7 ICC Publications.

International Code Council, 500 New Jersey Avenue, NW, 6th Floor, Washington, DC 20001.

International Fuel Gas Code (IFGC), 2012 2015 .

2.3.8 ISO Publications.

International Organization for Standardization Publications, 1 rue de Varembé, Case Postale 56, CH-1211Geneve 20, ISO Central Secretariat, Chemin de Blandonnet 8, CP 401, 1214 Vernier, GenevaSwitzerland .

ISO 10156, Gases and gas mixtures — Determination of fire potential and oxidizing ability for the selectionof cylinder valve outlets, 2010, Corrigendum, 2010 .

ISO 10298, Determination of toxicity of a gas or gas mixture, 2010.


Underwriters Laboratories Inc., 333 Pfingsten Road, Northbrook, IL 60062.

ANSI/ UL 723, Standard for Test of Surface Burning Characteristics of Building Materials, 2008, revised2010 2013 .

2.3.10 U.S. Government Publications.

U.S. Government Printing Government Publishing Office, 732 North Capitol Street, NW, Washington,DC 20402 20401-0001 .

Title 21, Code of Federal Regulations, Part 210, “Processing, Packing, or Holding Drugs; General.”

Title 21, Code of Federal Regulations, Part 211, “Current Good Manufacturing Practice for FinishedPharmaceuticals.”

Title 29, Code of Federal Regulations, Part 1910.1000, “Air Contaminants.”

Title 29, Code of Federal Regulations, Part 1910.1200, “Hazard Communication.”

Title 49, Code of Federal Regulations, Part 173, “Shippers — General Requirements for Shipments andPackages.”

2.3.11 Other Publications.

Merriam-Webster’s Collegiate Dictionary, 11th edition, Merriam-Webster, Inc., Springfield, MA, 2003.

2.4 References for Extracts in Mandatory Sections.







NFPA 318, Standard for the Protection of Semiconductor Fabrication Facilities, 2015 edition.


NFPA 5000® , Building Construction and Safety Code®, 2015 edition.


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Public Input No. 4-NFPA 55-2015 [Chapter I]




Street Address:

City:

State:

Zip:

Submittal Date: Mon Dec 21 14:25:59 EST 2015


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ASTM E84, Standard Test Method for Surface Burning Characteristics of Building Materials, 2014 2015

ASTM E136, Standard Test Method for Behavior of Materials in a Vertical Tube Furnace at 750°C,2012 2015 .

ASTM E681, Standard Test Method for Concentration Limits of Flammability of Chemicals (Vapors andGases), 2009.

ASTM E1529, Standard Test Methods for Determining Effects of Large Hydrocarbon Pool Fires onStructural Members and Assemblies, 2013 2014 .

ASTM E2652, Standard Test Method for Behavior of Materials in a Tube Furnace with a Cone-ShapedAirflow Stabilizer, at 750 Degrees C, 2012.


Date updates


Submitter Full Name: Timothy Earl


Street Address:

City:

State:

Zip:

Submittal Date: Mon Jan 04 13:17:16 EST 2016


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Underwriters Laboratories Inc., 333 Pfingsten Road, Northbrook, IL 60062.

ANSI/UL 723, Standard for Test of Surface Burning Characteristics of Building Materials, 2008, revised2010 2013 .


This proposal updates the referenced UL Standards to the current edition.




Street Address:

City:

State:

Zip:



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3.3.6.2 Indoor Area.

An area that is within a building or structure having overhead cover, other than a structure qualifying as“weather protection” in accordance with Section 6 . 6.


Manual of Style requires that no references to specific sections of a code or standard be included in a definition.

Moreover 6.6.1 already states that weather protection does not make an area an indoor area.




Street Address:

City:

State:

Zip:



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3.3.XX * Compressed Medical Gases (CMG). Any liquefied or vaporized gas alone or incombination with other gases that is a drug as defined by 201(g)(1) of the Federal Food, Drug, andCosmetic Act, 21USC321(g)(1).

A.3.3.XX CMG includes gas(es) recognized in the current USP-NF or supplement(s) andgas(es) intended for direct use or as a component of a gas(es) in the diagnosis, cure, mitigation,treatment, or prevention of diseases in man or in animals that achieves its intended purposethrough chemical rather than physical means.






Street Address:

City:

State:

Zip:



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3.3.29 Cryogenic Fluid Central Supply System.

An assembly of equipment designed to contain, distribute, or transport cryogenic fluids. for supplyingcompressed gas, including, but not limited to, a stationary tank(s) that is permenently installed throughanchoring to a foundation, pressure regulators, pressure relief devices, vaporizers, manifolds, andinterconnecting piping that is designed to be filled at the health care facility with a cryogenic fluid and thatterminates at the source valve. [99, 2018]

3.3.29.1 Bulk Cryogenic Fluid Central Supply System.

A cryogenic fluid central supply system with a storage capacity of more than 566 m 3 [20,000 ft 3 (scf)]. [99, 2018]

3.3.29.3 Micro-Bulk Cryogenic Fluid Central Supply System.

A cryogenic fluid central supply system with a storage capacity of less than or equal to 566 m 3 [20,000 ft 3

(scf)]. [99, 2018]


The NFPA 99/55 Task Group is proposing a new chapter for Cryogenic Fluid Central Supply Systems for Health Care Facilities. This change is to clarify the "name" or terminology used for this system and align the definition with NFPA 99.




Street Address:

City:

State:

Zip:



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Hydrogen Equipment Enclosure (HEE). A prefabricated area designed to protect hydrogen equipment that is

confined by at least 3 walls, not routinely occupied, and has a total area less than 450 ft 2 (41.8 m 2 ).


The definition for hydrogen equipment enclosures is not included in NFPA 55. It should be added for consistency with NFPA 2. The definition included in this public input should be updated consistent with the definition changes made in other public comments.




Street Address:

City:

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Zip:



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3.3.65 Material.

3.3.65.1 Inert Material

Non-flammable, non-reactive material.

3.3.65.2 Limited-Combustible Material.

See 4.12.2.

3.3.65.2 3 Noncombustible Material.

See 4.12.1.

3.3.65.3 4 Incompatible [Hazardous] Material.

Materials that, when in contact with each other, have the potential to react in a manner that generates heat,fumes, gases, or by-products that are hazardous to life or property. [400, 2016]


The term "inert material" is used in Section 10.4.3.1.7, but is not defined anywhere. As this section is extracted into NFPA 2 as well, requesting the agreed definition also be extracted into NFPA 2.




Affilliation: FCHEA

Street Address:

City:

State:

Zip:



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Press-Connect Fitting-

A permanent mechanical connection for joining copper tubing, steel and stainless steel pipe utilizingelastomeric seal or an elastomeric seal and corrosion-resistant grip ring or rings. Fitting connections aremade with a pressing tool and jaws or rings approved by the fitting manufacturer for use in accordance withthe product listing.


Currently there is no definition for Press-Connect fittings in NFPA 55. The term Press-Connect Fitting is used in both the IAPMO and ICC codes. The wide use of Mechanical type fittings has created the need to identify fittings such as Press-Connect and provide definitions to prevent confusion between mechanical fitting types and to help identify the correct standards these fittings are required to be listed to based upon the use of the fittings.. This definition is proposed to prevent confusion within the industry and aligns definitions for these type fittings. This definition will also help to prevent incorrect terminology in the industry such as referring to Press-Connect fittings as Propress which we have all commonly seen. As the Manufacturer of Propress we do like that our brand name is the name used by those in the industry when referring to Press-Connect fittings, but we do want the industry to have the correct terminology of the fittings to avoid any confusion between manufactured products.



Public Input No. 38-NFPA 55-2016 [Section No.9.4.1.4.1]

Press-Connect Fitting used in the body of thestandard.


Submitter Full Name: Mark Fasel

Organization: Viega Llc

Street Address:

City:

State:

Zip:



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3.3.94* Local Signal. A visible indication of the operating status of equipment. [ 99 , 2018]

A.3.3.94 Local Signal. Examples would include a gauge, a flag, a light, or some otherpossible manifestation that allows a maintenance person to stand at the equipment and know whatconditions are present (e.g., which header of cylinders is in service). The elements to be displayedare typically those that will also be monitored at the master alarm, but the local signal is visible atthe equipment rather than remotely. [ 99 , 2018]






Street Address:

City:

State:

Zip:



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*Hydrogen Equipment Enclosure (HEE). A prefabricated system, device or appliance designed tocontain hydrogen equipment that is confined by at least 3 walls and a roof , not routinely occupied, andhas a total area less than 450 ft2 (41.8 m2).

new annex note:

Hydrogen Equipment Enclosure (HEE). Hydrogen equipment enclosures can include repurposed “shipping”or

“ISO” containers as defined in Section 3.3.8 of NFPA 307: A reusable, intermodal boxlike structure of rigidconstruction fitted with devices to permit lifting and handling particularly transfer from one mode oftransportation to another mode of transportation.

Hydrogen equipment located in enclosures larger than the largest standard intermodal container (presently56 ft long x 8 ft wide x 9.5 ft high) typically are subject to the requirements for indoor installations.



The HEE may be designed to contain and control potential hydrogen leaks from hydrogen storage,compressors and other hydrogen fuel processing equipment, exterior walls may contain fire rating.



we should harmonize this definition with the content in NFPA -2




Affilliation: BoydH2 on behalf of Linde LLC

Street Address:

City:

State:

Zip:



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Persons engaged in storing, using, or handling [GH 2 or LH 2 ] shall be designated as operations

personnel and shall be trained in accordance with 4.11.1 and 4.11.2.1 through 4.11.3.2. [ 400: 6.1.4.2]

New Section after 4.11.2:

4.11.2.1 Persons performing public motor fuel dispensing of GH2 Vehicles in accordance with Chapter 10shall not be designated as operations personnel and shall not be subject to the requirements of 4.11.2.

Renumber subsequent sections.


Public Input is also being submitted to NFPA 2 (PI 300 NFPA 2: 2016)to address this issue. A literal application of existing requirement could result in a requirement to train members of the public who are simply refueling their GH2 powered vehicle beyond the simple requirements which can be addressed mostly by signage for a refueling operation. For a public fueling station in compliance with NFPA 2 Chapter 10, the need for additional training of public personnel is minimal - similar to how gasoline is handled. The text in this section is extracted into NFPA 2. Therefore the submitter respectfully requests this item be coordinated between NFPA 55 and NFPA 2 TCs.




Affilliation: FCHEA

Street Address:

City:

State:

Zip:



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4.11.1.2

Where guard posts are installed, the posts shall meet the following criteria:

(1) They shall be constructed of steel not less than 4 in. (102 mm) in diameter and concrete filled.

(2) They shall be spaced not more than 4 ft (1.2 m) between posts on center.

(3) They shall be set not less than 3 ft (0.9 m) deep in a concrete footing of not less than a 15 in.(381 mm) diameter.

(4) They shall be set with the top of the posts not less than 3 ft (0.9 m) above ground.

(5) They shall be located not less than 5 ft 3 ft (1 0 .5 m 9 m ) from the tank.

[400:6.1.9.2]


NFPA 400 first revision 20 (for the 2016 edition) changed the guard post distance from 5 feet to 3 feet.


Submitter Full Name: Karen Koenig

Organization: CGA

Street Address:

City:

State:

Zip:

Submittal Date: Mon May 02 09:30:24 EDT 2016


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6.1.1.1 Occupancy Requirements.

Occupancies containing that contain compressed gases and or cryogenic fluids shall comply with thischapter in addition to other applicable requirements of this code.


The provision intends to establish the requirement on the presence of either compressed gases or cryogenic fluids, not both compressed gases and cryogenic fluids.


Submitter Full Name: Jim Muir

Organization: Building Safety Division, Clark County, Washington

Affilliation: NFPA's Building Code Development Committee (BCDC)

Street Address:

City:

State:

Zip:



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6.3.1.1 Threshold Exceedences.


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Where the quantities of compressed gases or cryogenic fluids stored or used within an indoor control areaexceed those shown in Table 6.3.1.1, the area shall meet the requirements for Protection Levels 1 through5 in accordance with the building code, based on the requirements of 6.3.2.

Table 6.3.1.1 Maximum Allowable Quantity (MAQ) of Hazardous Materials per Control Area

Storage Use — Closed SystemsUse — O

System

Material Class

HighHazard

ProtectionLevel

SolidPounds

LiquidGallons

Gasa

scf (lb)Solid

PoundsLiquid

GallonsGasa

scf (lb)Solid

PoundsL

G

Cryogenicfluid

Flammable 2 NA 45b, c NA NA 45b,c NA NA

Oxidizing 3 NA 45d, e NA NA 45d,e NA NA

Inert NA NA NL NA NA NL NA NA

Flammable,

gasfGaseous 2 NA NA 1000d,e NA NA 1000d,e NA

Liquefied 2 NA NA (150)d,e NA NA (150)d,e NA

LP 2 NA NA (300)g,h,i NA NA (300)g NA

Inert gas Gaseous NA NA NA NL NA NA NL NA

Liquefied NA NA NA NL NA NA NL NA

Oxidizinggas

Gaseous 3 NA NA 1500d,e NA NA 1500d,e NA

Liquefied 3 NA NA (150)d,e NA NA (150)d,e NA

Pyrophoricgas

Gaseous 2 NA NA 50d,j NA NA 50d,j NA

Liquefied 2 NA NA (4)d,j NA NA (4)d,j NA

Unstable(reactive)gas

Gaseous4

or 3detonable 4

1 NA NA 10d,j NA NA 10d,j NA

3nondetonable3

2 NA NA 50d,e NA NA 50d,e NA

2 3 NA NA 750d,e NA NA 750d,e NA

1 NA NA NA NL NA NA NL NA

Unstable(reactive)gas

Liquefied

4 or 3detonable

1 NA NA (1)d,j NA NA (1)d,j NA

3nondetonable

2 NA NA (2)d,e NA NA (2)d,e NA

2 3 NA NA (150)d,e NA NA (150)d,e NA

1 NA NA NA NL NA NA NL NA

Corrosivegas

Gaseous 4 NA NA 810d,e NA NA 810d,e NA


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Storage Use — Closed SystemsUse — O

System

Material Class

HighHazard

ProtectionLevel

SolidPounds

LiquidGallons

Gasa

scf (lb)Solid

PoundsLiquid

GallonsGasa

scf (lb)Solid

PoundsL

G

Liquefied NA NA (150)d,e NA NA (150)d,e NA

Highly toxicgas

Gaseous 4 NA NA 20e,k NA NA 20e,k NA

Liquefied NA NA (4)e,k NA NA (4)e,k NA

Toxic gas Gaseous 4 NA NA 810d,e NA NA 810d,e NA

Liquefied NA NA (150)d,e NA NA (150)d,e NA

NA: Not applicable within the context of NFPA 55 (refer to the applicable building or fire code for additionalinformation on these materials).

NL: Not limited in quantity.

Notes:

(1) For use of control areas, see Section 6.2.

(2) Table values in parentheses or brackets correspond to the unit name in parentheses or brackets at thetop of the column.

(3) The aggregate quantity in use and storage is not permitted to exceed the quantity listed for storage. Inaddition, quantities in specific occupancies are not permitted to exceed the limits in the building code.

aMeasured at NTP [70°F (20°C) and 14.7 psi (101.3 kPa)].

bNone allowed in unsprinklered buildings unless stored or used in gas rooms or in approved gas cabinetsor exhausted enclosures, as specified in this code.

cWith pressure-relief devices for stationary or portable containers vented directly outdoors or to an exhausthood.

dQuantities are permitted to be increased 100 percent where stored or used in approved cabinets, gascabinets, exhausted enclosures, gas rooms, as appropriate for the material stored. Where Footnote e alsoapplies, the increase for the quantities in both footnotes is permitted to be applied accumulatively.

eMaximum quantities are permitted to be increased 100 percent in buildings equipped throughout with anautomatic sprinkler system in accordance with NFPA 13. Where Footnote d also applies, the increase forthe quantities in both footnotes is permitted to be applied accumulatively.

fFlammable gases in the fuel tanks of mobile equipment or vehicles are permitted to exceed the MAQwhere the equipment is stored and operated in accordance with the applicable fire code.

gSee NFPA 58 for requirements for liquefied petroleum gas (LP-Gas). LP-Gas is not within the scope ofNFPA 55.

hAdditional storage locations are required to be separated by a minimum of 300 ft (92 m).

iIn mercantile occupancies, storage of LP-Gas is limited to a maximum of 200 lb (91 kg) in nominal 1 lb(0.45 kg) LP-Gas containers.

jPermitted only in buildings equipped throughout with an automatic sprinkler system in accordance withNFPA 13.

kAllowed only where stored or used in gas rooms or in approved gas cabinets or exhausted enclosures, asspecified in this code.



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The proposed change removes the detonable and non-detonable subcategories from the Unstable Reactive Gas 3 (both gaseous and liquefied). The subcategories (detonable and non-detonable) should only apply to quantities greater than the MAQ. This change would make NFPA 55 more consistent with the requirements in the International Fire Code, which does not apply the sub-categorization until the Unstable Reactive 3 gas (both detonable and non-detonable combined) MAQ has been exceeded.

NFPA 55 does not provide a clear definition or other method for determining whether an Unstable Reactive gas 3 is detonable vs non-detonable. A clarification should be provided for detonable vs. non-detonable Unstable Reactive Gas 3. Note: HMEX provides the categorization for Unstable Reactive Gas 3 detonable and non-detonable. HMEX is intended to be used with the International Fire Code and International Building Code.




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6.3.1.5 Multiple Hazards.

Where When a compressed gas or cryogenic fluid has multiple hazards, all hazards shall be addressedand controlled in accordance with the provisions for the protection level for which the threshold quantity isexceeded.


The requirement is not locational. It is more appropriate to use "where."





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6.3.1.6.1

Flammable and oxidizing gases shall not be stored or used in other than industrial and storage occupanciesand laboratory areas of business occupancies not used for offices .


Flammable and Oxidizing gases >250 cu ft. in non office areas of a business occupancy is permitted by the IFC 5803.1.1. This change achieves consistency but clarifies further that only laboratory areas are permitted to have > 250 cu ft. Note that in areas of conflict the IFC shall have primacy over referenced codes (such as NFPA 55 in this case).

for reference: 2015 IFC: 5803.1.1 Special limitations for indoor storage and use.Flammable gases shall not be stored or used in Group A,E, I or R occupancies or in offices in Group B occupancies.Exceptions:1. Cylinders of nonliquefied compressed gases notexceeding a capacity of 250 cubic feet (7.08 m3)or liquefied gases not exceeding a capacity of 40pounds (18 kg) each at normal temperature andpressure (NTP) used for maintenance purposes,patient care or operation of equipment.2. Food service operations in accordance with Section6103.2.1.7.3. Hydrogen gas systems located in a hydrogen fuelgas room constructed in accordance with Section421 of the International Building Code.

2015 IFC: [A] 102.7 Referenced codes and standards. The codes andstandards referenced in this code shall be those that are listedin Chapter 80, and such codes and standards shall be consideredto be part of the requirements of this code to the prescribedextent of each such reference and as further regulatedin Sections 102.7.1 and 102.7.2.[A] 102.7.1 Conflicts. Where conflicts occur between provisionsof this code and referenced codes and standards,the provisions of this code shall apply.




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6.3.1.6.3

Hydrogen gas systems located in a hydrogen gas room that meets the requirements of 10.4.5.3 arepermissible in quantities up to those allowed by Table 6.3.1.1 in Assembly, Educational, Institutional,Residential, or Business occupancies.


Hydrogen gas rooms are not currently invoked by NFPA 55. This change is consistent with the IFC 5803.1.1 and provides a driver for building one. A hydrogen gas room in NFPA 55 is analogous to a "Hydrogen Fuel Gas Room" in the IFC. Its use is different from a gas room. A gas room can be used to double base MAQ but there is no driver for a hydrogen gas room currently. A hydrogen gas room can allow a hydrogen system to be built in other than industrial or storage occupancies with a system that is greater than 250 cu ft but less than MAQ and still be part of the base occupancy when the room is built per 10.4.5.3. This is appropriate and should be allowed.

2015 IFC: 5803.1 Quantities not exceeding the maximum allowablequantity per control area. The storage and use of flammablegases in amounts not exceeding the maximum allowablequantity per control area indicated in Section 5003.1 shall bein accordance with Sections 5001, 5003, 5801 and 5803.5803.1.1 Special limitations for indoor storage and use.Flammable gases shall not be stored or used in Group A,E, I or R occupancies or in offices in Group B occupancies.Exceptions:1. Cylinders of nonliquefied compressed gases notexceeding a capacity of 250 cubic feet (7.08 m3)or liquefied gases not exceeding a capacity of 40pounds (18 kg) each at normal temperature andpressure (NTP) used for maintenance purposes,patient care or operation of equipment.2. Food service operations in accordance with Section6103.2.1.7.3. Hydrogen gas systems located in a hydrogen fuelgas room constructed in accordance with Section421 of the International Building Code.



Public Input No. 74-NFPA55-2016 [Section No. 10.4.5.3]

both must be implemented together. PI 74 relocated requirements fromChapter 10 where they only apply to indoor bulk hydrogen systems.




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6.3.1.7 Toxic and Highly Toxic Compressed Gases.

Except for containers or cylinders not exceeding 20 scf (0.6 Nm3) content at NTP stored or used within gascabinets or exhausted enclosures of educational occupancies , toxic or highly toxic compressed gasesshall not be stored or used in other than industrial and storage occupancies.


The NFPA 400 (2016 Edition) occupancy specific MAQ tables 5.2.1.2 through 5.2.1.10.1, all allow toxic and highly toxic compressed gases in cylinders not exceeding 20 scf at NTP within exhausted cabinets or exhausted enclosures making the specific allowance for educational occupancies unnecessary. Delete Educational occupancy so that this requirement is consistent with the allowances within NFPA 400.




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Submittal Date: Wed Dec 16 11:05:23 EST 2015


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Indoor storage and use areas and storage buildings for compressed gases and cryogenic fluids shall beprovided with mechanical exhaust ventilation or fixed natural ventilation, where ventilation per 6.16.1 ormechanical exhaust ventilation per 6.16.2. Fixed natural ventilation is permissible, where fixed naturalventilation is shown to be acceptable for the material as stored.


Introduces the concept that exhaust ventilation (direct to the outside) does not kick in until >MAQ. At less than MAQ ventilation per the mechanical code is OK.




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6.16.1 Ventilation for Quantities Less Than or Equal to the MAQ

Ventilation systems shall be designed and installed in accordance with the requirements of the mechanicalcode.


Currently all requirements of 6.16 apply for any quantity. Below MAQ the only requirement should be that normal ventilation designed per he mechanical code is OK. For instance, bringing a lecture bottle of flammable gas into any occupancy would trigger the requirements of 6.16 currently. Most building do not meet these requirements and they are not needed for small quantities.




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6.16.2 Ventilation for Quantities Greater than MAQ

Ventilation for indoor rooms or areas with quantities of compressed gas or cryogenic fluids greater thanthose shown in Table 6.3.1.3 shall be in accordance with the requirements of 6.16.2.1 through 6.16.2.7.

Renumber existing 6.16.1 to 6.16.7 to 6.16.2.1 through 6.16.2.7.


The requirements of the existing 6.16.1 -7 are appropriate for quantities greater than MAQ but are excessive for < MAQ.




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6.16.3.2 Ventilation Rate.

Mechanical exhaust or fixed natural ventilation shall be provided at a rate of not less than 1 scf/min/ft2

(0.3048 Nm 0051m 3 / min/m sec •m 2 ) of floor area over the area of storage or use.


The metric units are supposed to be in SI units. SI doesn’t use minutes; only hours or seconds as defined in ANSI SI-10.



Organization: FCHEA


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6.16.4.4

For LH2 systems, exhaust shall be taken from a point within 12 in. (305 mm) of the cieling and inlets shallbe provided within 12 in. (305 mm) of the floor.

Please renumber subsequent sections


Release of LH2 are different in that the initial release will normally (but not always) be buoyant. regardless most of the release will quickly vaporize and warm up and become lighter than air. So exhaust near the ceiling is also appropriate and should be required. To assure that the room space is adequately swept with air, floor level intakes are also appropriate.




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7.1.5.5.2

Pressure relief devices are to conform to either stationary or transportable storage requirements basedon design and usage.

7.1.5.5.2.1 Pressure relief devices to protect transportable containers shall be designed and provided inaccordance with CGA S-1.1, Pressure Relief Device Standards – Part 1– Cylinders for Compressed Gases,for cylinders; CGA S-1.2, Pressure Relief Device Standards – Part 2 – Cargo and Portable Tanks forCompressed Gases, for portable tanks; and CGA S-1.3, Pressure Relief Device Standards – Part 3 –Stationary Storage Containers for Compressed Gases, for stationary tanks or in accordance with applicableequivalent requirements in the country of use.


The intent is to differentiate between transportable and stationary storage, as requirements and agencies for the two types are different. This issue for clarification by differentiation was identified in FCHEA review of NFPA 2, where extract text from NFPA 55 is used. The submitter requests consideration jointly between NFPA 55 and NFPA 2 as this differentiation would impact both documents.




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7.1.7.3.1

Stationary compressed gas cylinders, containers, and tanks shall be marked in accordance with NFPA 704or Hazardous Materials Identification System (HMIS) as the application dictates .


US DoL OSHA - 29 CFR 1910.1200 Hazardous Materials Identification may be applicable for some applications.




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7.1.8.3.2

Guard posts Bollards, guards or other approved means shall be provided to protect compressed gascylinders, containers, tanks, and systems indoors and outdoors from vehicular damage in accordance withSection 4.11.


Guard posts are security stations. Bollards are posts in the ground provided for protection from physical damage. If other means are provided, they should be approved, which is a defined term.





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Compressed Transportable compressed gas cylinders, containers, and tanks in use or in storage shall besecured to prevent them from falling or being knocked over by corralling them and securing them to a cart,framework, or fixed object by use of a restraint, unless otherwise permitted by 7.1.8.4.1 and 7.1.8.4.2.


Need to differentiate between transportable storage and stationary storage. This issue was identified in review of NFPA 2, for several sections of Chapter 7. The submitter requests this issue be considered jointly between NFPA 55 and NFPA 2 to facilitate coordination and harmonization.




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7.1.10 Separation from Hazardous Conditions.

7.1.10.1 General.

Compressed gas cylinders, containers, tanks, and systems in storage or use shall be separated frommaterials and conditions that present exposure hazards to or from each other.


Gas cylinders, containers, and tanks shall be separated in accordance with Table 7.1.10.2.

Table 7.1.10.2 Separation of Gas Cylinders, Containers, and Tanks by Hazard Class

Gas CategoryOtherGas

UnstableReactiveClass 2,

Class 3, orClass 4 Corrosive Oxidizing Flammable Pyrophoric

Toxic orHighlyToxic

ft m ft m ft m ft m ft m ft m

Toxic or highlytoxic

NR 20 6.1 20 6.1 20 6.1 20 6.1 20 6.1 — —

Pyrophoric NR 20 6.1 20 6.1 20 6.1 20 6.1 — — 20 6.1

Flammable NR 20 6.1 20 6.1 20 6.1 — — 20 6.1 20 6.1

Oxidizing NR 20 6.1 20 6.1 — — 20 6.1 20 6.1 20 6.1

Corrosive NR 20 6.1 — — 20 6.1 20 6.1 20 6.1 20 6.1

UnstablereactiveClass 2,Class 3, orClass 4

NR — — 20 6.1 20 6.1 20 6.1 20 6.1 20 6.1

Other gas — NR NR NR NR NR NR


7.1.10.2.1

Subparagraph 7.1.10.2 shall not apply to gases contained within closed piping systems.

7.1.10.2.2

The distances shown in Table 7.1.10.2 shall be permitted to be reduced without limit where compressedgas cylinders, containers, and tanks are separated by a barrier of noncombustible construction that has afire resistance rating of at least 0.5 hour and interrupts the line of sight between the containers.

7.1.10.2.3

The 20 ft (6.1 m) distance shall be permitted to be reduced to 5 ft (1.5 m) where one of the gases isenclosed in a gas cabinet or without limit where both gases are enclosed in gas cabinets.

7.1.10.2.4

Cylinders without pressure relief devices shall not be stored without separation from flammable andpyrophoric gases with pressure relief devices.

7.1.10.2.5*

Spatial separation shall not be required between cylinders deemed to be incompatible in gas productionfacilities where cylinders are connected to manifolds for the purposes of filling, analysis of compressedgases or, manufacturing procedures, assuming the prescribed controls for the manufacture of gas mixturesare in place.


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7.1.10.3* Clearance from Combustibles and Vegetation.

Combustible waste, vegetation, and similar materials shall be kept a minimum of 10 ft (3.1 m) fromcompressed gas cylinders, containers, tanks, and systems.

7.1.10.3.1

A noncombustible partition without openings or penetrations and extending not less than 18 in. (457 mm)above and to the sides of the storage area shall be permitted in lieu of the minimum distance.

7.1.10.3.2

The noncombustible partition shall be either an independent structure or the exterior wall of the buildingadjacent to the storage area.

7.1.10.4 Ledges, Platforms, and Elevators.

Compressed gas cylinders, containers, and tanks shall not be placed near elevators, unprotected platformledges, or other areas where compressed gas cylinders, containers, or tanks could fall distances exceedingone-half the height of the container, cylinder, or tank.

7.1.10.5 Temperature Extremes.

Compressed Transportable compressed gas cylinders, containers, and tanks, whether full or partially full,shall not be exposed to temperatures exceeding 125°F (52°C) or subambient (low) temperatures unlessdesigned for use under such exposure.

7.1.10.5.1

Compressed Transportable compressed gas cylinders, containers, and tanks that have not been designedfor use under elevated temperature conditions shall not be exposed to direct sunlight outdoors whereambient temperatures exceed 125°F (52°C). The use of a weather protected structure or shadedenvironment for storage or use shall be permitted as a means to protect against direct exposure to sunlight.

7.1.10.6 Falling Objects.

Compressed gas cylinders, containers, and tanks Stationary and transportable storage shall not be placedin areas where they are capable of being damaged by falling objects.

7.1.10.7 Heating.

Compressed Stationary and transportable compressed gas cylinders, containers, and tanks, whether fullor partially full, shall not be heated by devices that could raise the surface temperature of the container,cylinder, or tank to above 125°F (52°C) for transportable storage, or the design temperature limits in thecase of stationary storage .

7.1.10.7.1 Electrically Powered Heating Devices.

Electrical heating devices shall be in accordance with NFPA 70.

7.1.10.7.2 Fail-Safe Design.

Devices designed to maintain individual compressed gas cylinders, containers, and tanks at constanttemperature shall be designed to be fail-safe.

7.1.10.8 Sources of Ignition.

Open flames and high-temperature devices shall not be used in a manner that creates a hazardouscondition.

7.1.10.9 Exposure to Chemicals.

Compressed Stationary and transportable compressed gas cylinders, containers, and tanks shall not beexposed to corrosive chemicals or fumes that could damage cylinders, containers, tanks, or valve-protective caps.

7.1.10.10 Exposure to Electrical Circuits.

Compressed Stationary and transportable compressed gas cylinders, containers, and tanks shall not beplaced where they could become a part of an electrical circuit.


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7.1.10.10.1*

Electrical devices mounted on compressed gas piping, cylinders, containers, or tanks stationary ortransportable storage shall be installed, grounded, and bonded in accordance with the methods specified inNFPA 70 (NEC).


Seeking to make a clear distinction between stationary and transportable storage as requirements and agencies are different. This impacts NFPA 2, which has extracted these requirements from NFPA 55, where use of both types are common. Examples of areas of concern with potential misinterpretation of applicable requirements are as follows:

Inadvertent activation of the CGA S-1 valve. Stationary storage does not require S-1 valves. So this only applies to transportable storage.

The concern with stationary storage is the possibility of a pool fire under the storage. An appropriate approach might be to place the storage above grade, maybe a concrete slab, so that an untenable release of a liquid fuel cannot pool under the storage.

Other solutions to resolve this are possible. Request discussion between NFPA 55 and NFPA 2 TCs.




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Gas cylinders, containers, and tanks shall be separated in accordance with Table 7.1.10.2 .

Table 7.1.10.2 Separation of Gas Cylinders, Containers, and Tanks by Hazard Class

Gas Category Other Gas Unstable Reactive Class 2, Class 3, orClass 4 Corrosive Oxidizing Flammable Pyrophoric Toxic or Highly Toxic ft m ft m ft m ft m ft m ft m Toxic orhighly toxic NR 20 6.1 20 6.1 20 6.1 20 6.1 20 6.1 — — Pyrophoric NR 20 6.1 20 6.1 20 6.1 20 6.1— — 20 6.1 Flammable NR 20 6.1 20 6.1 20 6.1 — — 20 6.1 20 6.1 Oxidizing NR 20 6.1 20 6.1— — 20 6.1 20 6.1 20 6.1 Corrosive NR 20 6.1 — — 20 6.1 20 6.1 20 6.1 20 6.1 Unstable reactive Class 2,Class 3, or Class 4 NR — — 20 6.1 20 6.1 20 6.1 20 6.1 20 6.1 Other gas — NR NR NR NR NR NR


from incompatible materials by a minimum of 20 ft (6.1m).

7.1.10.2.1

Subparagraph 7.1.10.2 shall not apply to gases contained within closed piping systems.

7.1.10.2.2

The distances shown in Table 7.1.10.2 shall seperation shall be permitted to be reduced without limitwhere compressed gas cylinders, containers, and tanks are separated by a barrier of noncombustibleconstruction that has a fire resistance rating of at least 0.5 hour and interrupts the line of sight between thecontainers.

7.1.10.2.3

The 20 ft (6.1 m) distance shall be permitted to be reduced to 5 ft (1.5 m) where one of the gases isenclosed in a gas cabinet or without limit where both gases are enclosed in gas cabinets.

7.1.10.2.4

Cylinders without pressure relief devices shall not be stored without separation from flammable andpyrophoric gases with pressure relief devices.

7.1.10.2.5*

Spatial separation shall not be required between cylinders deemed to be incompatible in gas productionfacilities where cylinders are connected to manifolds for the purposes of filling, analysis of compressedgases or, manufacturing procedures, assuming the prescribed controls for the manufacture of gas mixturesare in place.

7.1.10.2.6

Spatial seperation shall not be required when incompatible solid and liquid materials are stored inapproved hazardous material storage cabinets


The use of a generic table for separation of gas cylinders (of different gas categories) presents unnecessary difficulties when storing gases of multiple gas categories. For example, per NFPA 55 7.1.10.2 a cylinder of chlorine gas (classified as an oxidizer and a toxic gas by HMEX(TM)) cannot be stored adjacent to a cylinder of oxygen (only classified as an oxidizer). Per NFPA 55, the cylinder of chlorine would require a special storage area for only oxidizer/toxics. Per available chemical compatibility sources, oxygen and chlorine gas would be chemically compatible and could be stored together.

Additionally, the reworded section would require separations from incompatible solids and liquids.



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Service, repair, modification, or removal of valves, pressure relief devices, or other compressed gascylinder, container, and tank stationary and transportable storage appurtenances shall be performed bytrained personnel and with the permission of the container owner.


Throughout this chapter we are seeking to clarify requirements through differentiation between stationary and transportable storage, as requirements may differ. Request this be addressed between NFPA 55 and NFPA 2 TCs as this impacts both.




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7.3.1.4 Valves Valve handles or actuators .

7.3.1.4.1

Valves utilized on compressed gas systems shall be designed for the gas or gases and pressure intendedand shall be accessible.

7.3.1.4.2

Valve handles or operators actuators for required shutoff valves not accessible to the public shall not beremoved or otherwise altered to prevent access.

7.3.1.4.3

Valves accessible to the general public shall be tamper resistant.


Access by the general public needs to be addressed. The AHJ has found with other fuel gases that historically tampering is a greater threat so they required standardized valves and the first responders carry the tools to close the valve.

Also PI attempts to clarify terminology. An operator is a person, an actuator is a device. A handle is a manual actuator.




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7.3.1.9 Transfer.

Transfer of gases between cylinders, containers, and tanks stationary and portable storage shall beperformed by qualified personnel using equipment and operating procedures in accordance with CGA P-1,Safe Handling of Compressed Gases in Containers.


Need to differentiate between stationary and transportable storage, as requirements differ.




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7.3.1.11.3

Manual emergency shutoff valves shall visually indicate their position, open or closed, and shall be 1/4 turnto shut off gas flow.


This adds basic requirement appropriate for emergency shutoff valves so that the position of a valve can be quickly determined visually and quickly closed from the open position.




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Public Input No. 75-NFPA 55-2016 [ Sections 7.3.1.12.1, 7.3.1.12.2, 7.3.1.12.3 ]

Sections 7.3.1.12.1, 7.3.1.12.2, 7.3.1.12.3

7.3.1.12.1

Where compressed gases gas sources in excess of the quantity thresholds in Table 6.3.1.1 and having ahazard ranking in one or more of the following hazard classes in accordance with NFPA 704 are carried inpressurized piping above a gauge pressure of 15 psi (103 kPa), an approved method of emergencyisolation shall be provided:

(1) Health hazard Class 3 or Class 4

(2) Flammability Class 4

(3) Instability Class 3 or Class 4

7.3.1.12.2

Approved means of meeting the requirements for emergency isolation shall include any of the following:

(1) Automatic shutoff valves, located as close to the bulk source as practical, tied to leak detectionsystems

(2) Attended control stations where trained personnel can monitor alarms or supervisory signals and cantrigger emergency responses

(3) A constantly monitored control station with an alarm and remote shut off of the gas supply system

(4) Excess flow valves at the bulk source

7.3.1.12.3

The requirements of 7.3.1.12 shall not be required for the following:

(1) Piping for inlet connections designed to prevent backflow at the source


(3) Where the source of the gas is not in excess of the quantity threshold as indicated in Table 6 . 3.1.1


no technical change intended. This simply relocates a key concept of this requirement to increase visibility and improve compliance.




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Containers employed for the storage or use of cryogenic fluids shall be designed, fabricated, tested, marked(stamped), and maintained in accordance with DOT regulations; Transport Canada (TC), Transportation ofDangerous Goods Regulations; the ASME Boiler and Pressure Vessel Code, “Rules for the Construction ofUnfired Pressure Vessels” ; or regulations of other administering agencies.


The text as written limits the user to Section VIII, when Section X or in some cases Section XII may be applicable. This section is extracted into NFPA 2, where we feel the limitation to Section VIII may not be appropriate. Request this issue be coordinated between NFPA 55 and NFPA 2.




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8.2.4.1.1

Pressure relief devices shall be provided to protect containers and piping systems containing cryogenicfluids from rupture in the event of damage due to overpressure.


Leak and deformation are not rupture. Rupture is a catastrophic event. We are also concerned about any loss of containment or any damage which may lead to a catastrophic event. Request this item be discussed jointly between NFPA 55 and NFPA 2.




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8.2.4.1.2

Pressure relief devices shall be designed in accordance with ASME, or in accordance with CGA S-1.1,Pressure Relief Device Standards — Part 1 — Cylinders for Compressed Gases, and CGA S-1.2, PressureRelief Device Standards – Part 2 – Cargo and Portable Tanks for Compressed Gases, for portable tanks;and CGA S-1.3, Pressure Relief Device Standards – Part 3 — Stationary Storage Containers forCompressed Gases, for stationary tanks.


Provide option to use appropriate ASME relief valves. Valves meeting ASME requirements are suitable for these applications.




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8.2.4.2 Containers Open to the Atmosphere.

Portable containers that are open to the atmosphere and are designed to contain cryogenic fluids atatmospheric pressure shall not be required to be equipped with pressure relief devices.

Note to TC: Request for clarification or pointer: For flammable gases such as hydrogen, how is the boil-offissue addressed?


Hydrogen is a flammable gas which will experience boil-off. It is not clear how this is addressed by the requirements stated. Requesting clarification or pointers to appropriate text. Also request this item be discussed jointly with NFPA 2 TC.




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(A) A copy of the schematic shall be included with the application operations and maintenanceinstructions.


The schematic may be important for operations and maintenance. A copy should be with the site O&M and possibly LOTO instructions.




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8.5 Medical Cryogenic Systems.

8.5.1

Bulk cryogenic fluid systems in medical gas applications at health care facilities shall be in accordancewith Chapter 8 , 1.1.2(3) , and the material-specific requirements of Chapter 9 as applicable.

8.5.1.1

Bulk cryogenic fluid systems shall be in accordance with the following provisions as applicable:

(1) Where located in a court, systems shall be in accordance with 8.13.2.7.2 .

(2) Where located indoors, systems shall be in accordance with 8.14.11.1 .

(3) Systems shall be installed by personnel qualified in accordance with CGA M-1, Guide for MedicalGas Installations at Consumer Sites , or ASSE 6015, Professional Qualification Standard for BulkMedical Gas Systems Installers .

(4) Systems shall be installed in compliance with Food and Drug Administration Current GoodManufacturing Practices as found in 21 CFR 210 and 21 CFR 211.

8.5.1.2

The following components of the bulk system shall be accessible and visible to delivery personnel duringfilling operations:

(1) Fill connection

(2) Top and bottom fill valves

(3) Hose purge valve

(4) Vent valve

(5) Full trycock valve

(6) Liquid level gauge

(7) Tank pressure gauge

8.5.1.3

Bulk cryogenic fluid systems shall be anchored with foundations in accordance with the provisions of CGAM-1, Guide for Medical Gas Installations at Consumer Sites .


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8.5.1.4

Bulk cryogenic fluid systems shall consist of the following:

(1) One or more main supply vessel(s), whose capacity shall be determined after consideration of thecustomer usage requirements, delivery schedules, proximity of the facility to alternative supplies, andthe emergency plan

(2) A contents gauge on each of the main vessel(s)

(3) A reserve supply sized for greater than an average day's supply, with the size of vessel or number ofcylinders being determined after consideration of delivery schedules, proximity of the facility toalternative supplies, and the facility's emergency plan

(4) At least two main vessel relief valves and rupture discs installed downstream of a three-way(three-port) valve

(5) A check valve located in the primary supply piping upstream of the intersection with a secondarysupply or reserve supply

8.5.1.5

Bulk cryogenic fluid reserve supply systems consisting of either a second cryogenic fluid source or acompressed gas source shall include the following:

(1) When the reserve source is a compressed gas source, the reserve shall be equipped with thefollowing:

(2) A cylinder manifold having not less than three gas cylinder connections or as otherwiserequired for an average of one day’s gas supply

(3) A pressure switch to monitor the pressure in the cylinder manifold

(4) When the reserve source is a second cryogenic fluid vessel, the reserve tank shall be equipped withthe following:

(5) An actuating switch or sensor to monitor the internal tank pressure

(6) A contents gauge to monitor the liquid level

(7) When the reserve source is either a cryogenic fluid or compressed gas source, a check valve shallbe provided to prevent backflow into the reserve system

8.5.1.6

Bulk cryogenic fluid systems shall include a fill mechanism consisting of the following components:

(1) A nonremovable product-specific fill connection in compliance with CGA V-6, Standard CryogenicLiquid Transfer Connection

(2) A means to cap and secure the fill connection inlet

(3) A check valve to prevent product backflow from the fill inlet


(5) Supports that hold the fill piping off the ground

(6) A secure connection between the bulk tank and the fill piping

(7) Supports as necessary to hold the fill line in position during all operations associated with the fillingprocedure


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8.5.1.7

Where vaporizers are required to convert cryogenic liquid to the gaseous state, the vaporizer units shallconform to the following:

(1) Be permitted to operate by either ambient heat transfer or external thermal source (e.g., electricheater, hot water, steam)

(2) Be designed to provide capacity for the customer’s peak and average flow rates under localconditions, seasonal conditions for weather and humidity, and structures that obstruct air circulationflow and sunlight

(3) If switching is required as part of the system design, have piping and manual/automatic valvingconfigured in such a manner that operating vaporizer(s) or sections of the vaporizer can be switchedto nonoperating vaporizer or section of the vaporizer to de-ice through a valving configuration thatensures continuous flow to the facility through either or both vaporizers and/or sections of thevaporizer if valving switchover fails

8.5.1.8

Where a vaporizer requires an external thermal source, the flow from the source of supply shall beunaffected by the loss of the external thermal source through either of the following:

(1) Reserve ambient heat transfer vaporizers capable of providing capacity for at least one day'saverage supply and piped so as to be unaffected by flow stoppage through the main vaporizer

(2) A reserve noncryogenic source capable of providing at least one day’s average supply

8.5.1.9 Small Medical Bulk Systems. (Reserved)





Public Input No. 91-NFPA 55-2016 [Global Input]




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8.8.1 General.

Electrical wiring and equipment shall be in accordance with NFPA 70 or NFPA 79 as appropriate, andSection 8.8.


NPFA 79 is not currently referenced. While NFPA 70 applies between components and the grid, NFPA 79 applies within systems and modules (e.g. – what if you have five 110 circuits in the same box? What are the color code and labeling requirements?)




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8.9.1.1 Testing.

Containers out of service in excess of 1 year shall be inspected and tested as required in 8.9.1.2 and ??? .


The text currently requires only the relief device be tested and inspected. The section is not directing to requirements for testing the container itself. Such requirements may differ depending on whether the storage is a transportable system or a stationary system. Request coordinating any change with NFPA 2, as this language is extracted into NFPA 2, and the issue was identified in a review on NFPA 2.




Affilliation: FCHEA

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Public Input No. 79-NFPA 55-2016 [ Section No. 8.13.2.6.4 [Excluding any Sub-Sections]

]

The grade elevation differential for a distance of not less than 50 ft (15.2 m) from where cryogenic fluidstorage or delivery systems are installed shall be higher than the grade on which such that a release willnot flow into an area where other flammable or combustible liquids are stored or used.


The word "grade" is confusing as it can be interpreted to mean an average change in elevation. Proposed rewording is intended to clarify the intent.




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8.14.2.2

Piping systems shall be designed and constructed to allow for expansion, contraction, vibration, settlement,and fire exposure .


Request for clarification: Is the fire exposure requirement pertaining to insulation? Other than fire exposure, the requirement is redundant to calling out the Piping Code. Please clarify intent.




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8.14.9.2.1

Container systems equipped with cathodic protection shall be inspected for the intended operation by acathodic protection tester.

8.14.9.2.1.1

The examinations shall be documented. A record of the examination history shall be maintained by theowner and shall be available to the authority having jurisdiction upon reques


Results of testing currently required need to be made available to the AHJ. This PI adds language for this. Request coordinating with NFPA 2 TC as this requirements has been extracted into NFPA 2, and the documentation addition would be applicable there as well.




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8.14.9.3.1

Systems equipped with impressed current cathodic protection systems shall

be inspected in accordance with the requirements of the design and

be examined for the intended operation by a qualified examiner.

8.14.9.

2

3 . 1.1

The examinations shall be documented.

8.14.9.3.2

The design limits shall be available to the AHJ upon request.

8.14.9.3.3

The system owner shall maintain the following records to demonstrate that the cathodic protection is inconformance with the requirements of the design: A record of the examination history shall be maintainedby the owner and shall be available to the authority having jurisdiction upon request.

(1) The results of inspections the examinations of the system

(2) The results of testing that has been completed report indicating that the impressed current system isoperating properly and that the corrosion of the hardware being protected has not exceeded safetymargins.


Clarifying the requirements and ensuring appropriate records are maintained. Differentiating terminology. Equipment is examined. Paperwork is inspected.




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9.1.1.2

A bulk oxygen An oxygen cryogenic fluid central supply system used in medical gas applications shall bein be in accordance with Section 8.5 and Chapter 17 and CGA M-1, Guide Standard for Medical GasInstallations at Consumer Sites Supply Systems at Health Care Facilities , in addition to the provisionsstated herein.





Public Input No. 91-NFPA 55-2016 [Global Input]




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Oxygen systems located outdoors shall be separated from exposure hazards in accordance with therequirements of Table 9.3.2 as applicable.

Table 9.3.2 Minimum Separation Distances Between Bulk Liquid Oxygen Systems and Exposure Hazards

Distance(See 9.3.2.1 .)

Type of Exposure ft m

(1) Buildings of Type I and II construction as defined by the building code 1 0.3

(2) Buildings of Type III, IV, or V construction as defined by the building code 50 15

(3) Wall openings as measured from high-pressure gas or liquefied gas regulators,pressure relief devices, vaporizers, manifolds, and interconnected piping

10 3

(4) Property lines 5 1.5

(5) Public sidewalks 10 3

(6) Public assembly 50 15

(7) Areas occupied by nonambulatory patients as measured from the primary pressurerelief device discharge vent and from filling and vent connections

50 15

(8) Parked vehicles 10 3

(9) Exterior walls that encroach on the container to form a court with three or more sides See 8.13.2.7

(10) All classes of flammable and combustible liquids above ground (See 9.3.2.2.)

(a) 0 gal to 1000 gal (0 to 3785 L) 25 7.5

(b) Over 1000 gal (3785 L) 50 15

(11) All classes of flammable and combustible liquids in belowground tanks or vaults

(a) Horizontal distance from oxygen storage container to tank or vault 15 4.6

(b) Horizontal distance from oxygen storage container to filling and vent connections orother openings to tank or vault

25 7.5

(12) Flammable gases aboveground

(a) Liquefied hydrogen (any quantity) 75 22.5

(b) Other liquefied gas, 0 gal to 1000 gal (0 L to 3785 L) 25 7.5

(c) Other liquefied gas, over 1000 gal (3785 L) 50 15

(d) Nonliquefied or dissolved gases, 0 scf to 25,000 scf (0 Nm3 to 708 Nm3) 25 7.5

(e) Nonliquefied or dissolved gases, over 25,000 scf (708 Nm3) 50 15

(13) Rapidly burning solids, including, but not limited to, excelsior, paper, or combustiblewaste

50 15

(14) Slowly burning solids, including, but not limited to, heavy timber or coal 25 7.5

(15) Inlets to underground sewer or drainage systems from liquid delivery connections,pressure relief device outlets, mobile supply equipment, and liquid withdrawal connections

8 2.5

(16) Areas below connections where liquid can fall during loading or unloading operationsand system operation from combustible surfaces, including, but not limited to, asphalt orbitumastic paving and expansion joint fillers (See 9.3.2.3.)

3 1

(17) Encroachment by overhead utilities

(a) Horizontal distance from the vertical plane below the nearest overhead wire of anelectric trolley, train, or bus line

50 15

(b) Horizontal distance from the vertical plane below the nearest overhead electrical wireother than those noted in (a)

5 1.5

(c) Piping containing other hazardous materials 15 4.6

(18)* Aboveground exposed piping and piping components of flammable gas systems,including piping systems below ground

15 4.6



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The phrase “including piping systems below ground” is vague and could be interpreted to apply to either underground flammable gas piping systems or to underground oxygen piping systems.



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9.4.1.4.1

Joints in piping and tubing shall be permitted to be made by welding or brazing or by use of flanged,threaded, socket, slip, compression or compression press-connect fittings.


Press-Connect fittings have been allowed for use as Compression fittings currently. This proposal will help to define the difference between a true compression fitting and a press-connect fitting as to which a definition is being provided in the related Public Input Number 37. This clarification and addition of press-connect language will help to remove confusion within the industry as well as provide the correct terminology for the fitting which is needed to refer to the related standards and ASME B 31 listings. This terminology and definition of press-connect fittings are used in both the ICC and IAPMO codes.

There is no cost associated with this proposal.





Submitter Full Name: Mark Fasel

Organization: Viega Llc

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10.1.3 Quantities Greater Than 5000 scf (141.6 Nm3).

The storage, use, and handling of hydrogen in gaseous hydrogen systems (bulk gaseous hydrogen

systems) in quantities greater than 5000 scf (141.6 Nm3) shall be in accordance with Sections 10.1, 10.2,10.3, and 10.4 and with ANSI/CGA H-5, Standard for Bulk Hydrogen Supply Systems .


CGA H-5 provides more details for bulk hydrogen supply systems.



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Bulk Hydrogen Storage Connected to Hydrogen Fuel Dispensing System

Bulk hydrogen storage connected to an intelligent fueling station shall comply with the requirements ofNFPA 2.


This is a placeholder to allow the TCs for NFPA 55 and NFPA 2 to work together to develop clearer distinction between requirements for bulk storage plugged into a building versus connected to an intelligent fueling station with robust safety protocols. (Personnel dealing with these 2 scenarios are different at hydrogen supply companies, as they are very different markets.)



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10.2.5.3

Control circuits that automatically shut downWhen an automatic shutdown control shuts down a system, the system shall remain down until manuallyactivated or reset

after a safe shutdown is performedby personnel authorized by the owner after determination of the cause of the shut down and thedetermination that the system is safe to restart .


Clarification. Existing sentence is confusing.




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10.2.6 Operation and Maintenance.

10.2.6.1 Operating Instructions.

10.2.6.1.1

For installations that require any operation of equipment by the user, the user shall be instructed in theoperation of the equipment and emergency shutdown procedures.

10.2.6.1.2

Instructions shall be maintained at the operating site at a location acceptable to the authority havingjurisdiction.

10. 2 3 .6 .2 Maintenance.

10. 2 3 .6. 2. 1

Maintenance shall be performed annually by a qualified representative of the equipment owner.

10. 2 3 .6.2 .2

The maintenance shall include inspection for physical damage, leak tightness, ground system integrity, ventsystem operation, equipment identification, warning signs, operator information and training records,scheduled maintenance and retest records, alarm operation, and other safety-related features.

10. 2 3 .6. 2. 3

Scheduled maintenance and retest activities shall be formally documented, and records shall be maintaineda minimum of 3 years.


As currently written, the maintenance of hydrogen systems would be required annually for all systems regardless of whether the quantities are less than or greater than Maximum Allowable Quantities. This is a significant change from the maintenance philosophy in the previous editions of NFPA 55.

Changing the section number puts this requirement into a section that would only be required if the quantities were greater than the MAQ. This would also make the requirement consistent with annual maintenance requirement for flammable gas systems found in NFPA 400 (2016 Edition) section 21.3.6.5. This would also make it consistent with the maintenance requirements for hydrogen systems found in the previous NFPA 55 Edition (2013) Chapter 10.




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Submittal Date: Fri Apr 08 14:34:48 EDT 2016


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Metal hydride storage system cylinders, containers, and tanks shall be inspected, tested, and requalified forservice at not less greater than 5-year intervals.


The need is to have containers inspected at intervals of 5 years or less. The revision clarifies this.




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Metal hydride storage system cylinders, containers, and tanks shall be inspected, tested, and requalified forservice at intervals not less to exceed than 5-year intervals years .


Clarification. As written, the requirement may be interpreted to mean that inspection intervals are greater than 5 years.




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Hydrogen Equipment Enclosures

Hydrogen equipment enclosures shall be in accordance with NFPA 2.


There could be jurisdictions that require compliance with NFPA 55 but not NFPA 2. The reference is needed to ensure that the requirements for Hydrogen Equipment Enclosure are addressed by NFPA 55.




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10.4.2.2 Location.

10.4.2.2.1* Minimum Distance.


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The minimum distance from a bulk hydrogen compressed gas system located outdoors to specifiedexposures shall be

in accordance with Table 10.4.2.2.1(a) , Table 10.4.2.2.1(b) , or Table 10.4.2.2.1(c) . (See alsoAnnex G .)

Table 10.4.2.2.1(a) Minimum Distance (D) from Outdoor Bulk Hydrogen Compressed Gas Systems toExposures — Typical Maximum Pipe Size

Pressure > 15 to ≤250 psig > 250 to ≤3000 psig > 3000 to ≤7500 psig > 7500 to ≤15,000 psig Internal PipeDiameter (ID) >103.4 to ≤1724 kPa >1724 to ≤20,684 kPa >20,684 to ≤51,711 kPa >51,711 to≤103,421 kPa d mm d = 52.5 mm d = 18.97 mm d = 7.31 mm d = 7.16 mm Group 1 Exposures

m ft m ft m ft m ft (a) Lot lines 12 40 14 46 9 29 10 34 (b) Air intakes (HVAC, compressors,other) (c) Operable openings in buildings and structures (d) Ignition sources such as open flames andwelding Group 2 Exposures m ft m ft m ft m ft (a) Exposed persons other than thoseservicing the system 6 20 7 24 4 13 5 16 (b) Parked cars Group 3 Exposures m ft m ft m ft mft (a) Buildings of noncombustible non-fire-rated construction 5 17 6 19 4 12 4 14 (b) Buildings ofcombustible construction (c) Flammable gas storage systems above or below ground (d) Hazardousmaterials storage systems above or below ground (e) Heavy timber, coal, or other slow-burningcombustible solids (f) Ordinary combustibles, including fast-burning solids such as ordinary lumber,excelsior, paper, or combustible waste and vegetation other than that found in maintained landscapedareas (g) Unopenable openings in building and structures (h) Encroachment by overhead utilities(horizontal distance from the vertical plane below the nearest overhead electrical wire of building service)(i) Piping containing other hazardous materials (j) Flammable gas metering and regulating stations such asnatural gas or propane

Table 10.4.2.2.1(b) Minimum Distance (D) from Outdoor Bulk Hydrogen Compressed Gas Systems toExposures by Maximum Pipe Size with Pressures >15 to ≤3000 psig

>15 to ≤250 psig

>103.4 to ≤1724 kPa >250 to ≤3000 psig

>1724 to ≤20,684 kPa Pressure Exposures *† Exposures *† Internal Pipe Diameter (ID) Group 1 Group 2Group 3 Group 1 Group 2 Group 3 ID

(in.) d

(mm) D = 0.231d D = 0.12584d - 0.47126 D = 0.096d D = 0.738d D = 0.43616d - 0.91791 D =0.307d m ft m ft m ft m ft m ft m ft 0.2 5.1 1 4 0 1 0 2 4 12 1 4 2 5 0.3 7.6 2 6 0 2 1 2 6 18 2 8 2 8 0.4 10.2 2 8 1 3 1 3 7


* For a list of exposures in each exposure group see Column 1 of Table 10.4.2.2.1(a).

† When calculating the minimum separation distance (D) using the formulas indicated, based on theexposure group and pressure indicated, the internal pipe diameter (d) is entered in millimeters (mm). Thecalculated distance (D) is expressed in units of measure in meters (m). To convert distance (D) to units ofmeasure in feet, multiply the value of (D) in meters by 3.2808 and round to the nearest whole foot.

Table 10.4.2.2.1(c) Minimum Distance (D) from Outdoor Bulk Hydrogen Compressed Gas Systems toExposures by Maximum Pipe Size with Pressures >3000 to ≤15,000 psig

>3000 to ≤7500 psig

>20,684 to ≤51,711 kPa >7500 to ≤15,000 psig

>51,711 to ≤103,421 kPa Pressure Exposures *† Exposures *† Internal Pipe Diameter (ID) Group1 Group 2 Group 3 Group 1 Group 2 Group 3 ID

(in.) d

(mm) D = 1.105d D = 0.68311d - 1.3123 D = 0.459d D = 1.448d D = 0.92909d - 1.6813 D =0.602d m ft m ft m ft m ft m ft m ft 0.2 5.1 6 18 2 7 2 8 7 24 3 10 3 10 0.3 7.6 8 28 4 13 3 11 11 36 5 18 5 15 0.4 10.2


* For a list of exposures in each exposure group see Column 1 of Table 10.3.2.1(a).

† When calculating the minimum separation distance (D) using the formulas indicated, based on theexposure group and pressure indicated, the internal pipe diameter (d) is entered in millimeters (mm). Thecalculated distance (D) is expressed in units of measure in meters (m). To convert distance (D) to units ofmeasure in feet, multiply the value of (D) in meters by 3.2808 and round to the nearest whole foot.


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10.4.2.2.1.1

The separation distance for piping systems with internal diameters other than those specified in Table10.4.2.2.1(a) for the pressure range selected shall be permitted with tabular distances determined basedon the use of Table 10.4.2.2.1(b) or Table 10.4.2.2.1(c) .

10.4.2.2.2 Maximum Internal Diameter of Interconnecting Piping.

The maximum internal diameter of the piping system used for interconnecting piping between the shutoffvalve on any single storage container to the point of connection to the system source valve shall not berequired to be in accordance with the values shown in Table 10.4.2.2.1(a) when in accordance withTable 10.4.2.2.1(b) or Table 10.4.2.2.1(c) .

10.4.2.2.2.1 * Determination of Internal Diameter.

The internal diameter of the piping system shall be determined by the diameter of the piping serving that

portion of a storage array with content greater than 5000 scf (141.6 Nm 3 ). The piping system size used inthe application of Table 10.4.2.2.1(a) , Table 10.4.2.2.1(b) , or Table 10.4.2.2.1(c) shall be determinedbased on that portion of the system with the greatest maximum internal diameter.

10.4.2.2.2.2

Separation distances determined based on the use of Table 10.4.2.2.1(b) or Table 10.4.2.2.1(c) shall besubject to review and approval by the AHJ.

10.4.2.2.3 *

Determination of System Pressure. The system pressure shall be determined by the maximum

operating pressure of the storage array with content greater than 5000 scf (141.6 Nm 3 ), irrespective ofthose portions of the system elevated to a higher pressure.

10.4.2.2.4 * Reduction of Distance by Mitigation Means.


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10.4.2.2.4.1 * Passive Means.

Except for distances to air intakes, the distances to Group 1 and 2 exposures shown in Table10.4.2.2.1(a) , Table 10.4.2.2.1(b) , and Table 10.4.2.2.1(c) shall be permitted to be reduced by one-halfand shall not apply to Group 3 exposures where fire barrier walls are located between the system and theexposure and constructed in accordance with the following:

(1) Fire barrier walls shall have a minimum fire resistance rating of not less than 2 hours.

(2) The fire barrier wall shall interrupt the line of sight between the bulk hydrogen compressed gassystem and the exposure.

(3) The configuration of the fire barrier shall allow natural ventilation to prevent the accumulation ofhazardous gas concentrations.

(4) The number of fire barrier walls used to separate individual systems shall be limited to three.

(5) The fire barrier wall shall not have more than two sides at 90 degrees (1.57 rad) directions or notmore than three sides with connecting angles of 135 degrees (2.36 rad).

(6)

(7) Fire barrier walls shall be designed and constructed as a structure in accordance with therequirements of the building code without exceeding the specified allowable stresses for the materialsof construction utilized. Structures shall be designed to resist the overturning effects caused by lateralforces due to wind, soil, flood, and seismic events.

(8) Where clearance is required between the bulk hydrogen compressed gas system and the barrierwall for the performance of service or maintenance-related activities, a minimum horizontal clearanceof 5 ft (1.5 m) shall be provided between the structure and the system.

(9) The fire barrier wall shall be either an independent structure or the exterior wall of the buildingadjacent to the storage or use area when the exterior building wall meets the requirements for firebarrier walls.

10.4.2.2.4.2 * Active Means.

Active control systems that mitigate the risk of system leaks and failures shall be permitted to be used as ameans to reduce separation distances where approved by the AHJ under the authority as granted bySection 1.5 .

10.4.2.2.5 Required Separation Distance for All Systems.

Separation distances shall be required for bulk hydrogen compressed gas systems independent of systempressure or internal diameter of piping systems in accordance with 10.4.2.2.5.1 through 10.4.2.2.5.3 .

10.4.2.2.5.1

Unloading connections on delivery equipment shall not be positioned closer to any of the exposures citedin Table 10.4.2.2.1(a) , Table 10.4.2.2.1(b) , or Table 10.4.2.2.1(c) than the distances given for thestorage system.

10.4.2.2.5.2

The minimum separation distance between gaseous and liquid systems integrated into a single systemwhere the liquid source is vaporized, compressed, and stored in the gaseous state shall be 15 ft (4.6 m).

10.4.2.2.5.3

Systems within 50 ft (15 m) of aboveground storage of all classes of flammable and combustible liquidsshall be located on ground higher than such storage, except where dikes, diversion curbs, grading, orseparating solid walls are used to prevent accumulation of these liquids under the system.

10.4.2.2.6 *

* The connecting angles between fire barrier walls shall be permitted to be reduced to lessthan 135 degrees (2.36 rad) for installations consisting of three walls when in accordance with8.13.2.7.2 .


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Bulk hydrogen compressed gas systems shall be allowed to integrate or co-locate other nonliquefiedflammable gas systems as a component of the hydrogen gas system without separation, where the outputof the system is designed to deliver a product in which the gases are mixed or blended for delivery into theuser’s system.

10.4.2.2.6.1

The following provisions shall apply in order to allow adjacent storage:

(1) The tubes shall be designed, built, and stamped in accordance with the ASME Boiler and PressureVessel Code , Section VIII, Division 1 or approved by the DOT or the TC for use as an exemptedcompressed gas shipping container.

(2) Hydrogen manifolds shall be designed and tested in accordance with ASME B31.12, HydrogenPiping and Pipelines , to ensure initial leaktightness. Other gas manifolds shall be designed andtested in accordance with ASME B31.3, Process Piping .

(3) Pressure relief devices protecting storage vessels excluding cylinders with a water volume less than

20 ft 3 (566 L) shall meet design requirements and be piped to a vent system that has beendesigned and installed in accordance with CGA G-5.5, Hydrogen Vent Systems .

(4) Where systems are provided with an emergency shutdown device, the device shall be common toall the co-located flammable gases. An event that causes the shutdown or isolation of the hydrogensystem shall simultaneously shut down or isolate the other flammable gas system.

20 ft. (See also Annex G .)



20_ft_Option_Substantiation.docxThis file contains the substantiation for the 20 ft approach.

55-2016_Chapter_10_20_ft_proposal.docxThis file contains the actual proposed changes in Word which are easier to read.


See attached Word file document.Separate files for the proposal and the substantiation.




Street Address:

City:

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Zip:



83 of 122 7/13/2016 10:38 AM

684 of 745

Proposal to Modify Setback Distances for Bulk Gaseous Hydrogen Storage

Substantiation:

SIMPLER 20 FOOT OPTION

The subject of separation distances is one of the most complicated issues in the code to properly apply

in developing bulk gaseous hydrogen systems. The subject has been thoroughly researched and refined

over the last 2-3 code cycles. This work has resulted in a technically defensible set of separation

distances in the code with background substantiation that provided the technical committee a strong

basis to modify previous values in the 2010, 2013 and 2016 editions of NFPA 55.

I chaired the original task group that put together the basis for the code changes that appeared in the

2010 edition. This was a significant effort and could not have been completed without the expertise of

the Industry partners that participated and provided expert pertinent input as well as the support of the

Department of Energy and notably the scientists from Sandia National Lab (DOE funded) who developed

and executed many of the calculations and models needed to create a scientific based methodology that

was documented, repeatable and revisable. These efforts were ultimately successful and resulted in the

body of technical supporting substantiation behind the separation distance revisions that appeared in

the 2010 edition and remain part of the code today.

As often happens when an issue is thoroughly researched by a group of detail oriented experts, the

resulting requirements, though viewed as a straightforward and logical result by the authors, are

complicated. Complicated requirements are difficult to apply as intended by designers, reviewers and

enforcers charged with applying the code to assure public safety. The results were separation distances

that varied by system pressure, exposures and pipe sizes. One could devote a significant effort

determining which requirements apply to a given system. This process would need to be repeated for

the designers, reviewers and enforcers to conclude that a given installation is indeed code compliant.

Simplifications were called for.

In the 2013 and 2016 editions of the code, additional refinements were made, mostly towards the goal

of simplifying the application of the requirements. These efforts were successful as well and resulted in

incremental improvements.

Another significant effort was initiated for the development of input to the 2019 Edition. Again with

significant support of both Industry and DOE. Because the previous methodology was documented,

retrievable and revisable, the group revisited several of the key input assumptions to determine if

revisions were warranted. This group effort resulted in a Public Input on behalf of the Task Group that

proposes several changes to the separation distances and is a solid and technically justifiable proposal

warranting TC consideration. If fact, much of the substantiation for that Public Input is included below

and applies equally well to this PI.

Through this beneficial development process, I considered the big picture implications of the issue of

separation distances in general and developed this PI alone, based on the work of the task group but

Formatted: Centered

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neither reviewed or endorsed by the task group. This PI is a solo effort that builds on the good work of

the Task Group.

A case for significant simplification can be made. When one considers the overall fire risk of bulk

hydrogen systems, separation distances are actually one of the last resort protective measures to

control fire risk. While valid, they assume that significant incidents have occurred, such that separation

distances are the last resort, after the fact, mitigation to prevent an already bad incident from getting

worse. Separation distances are important and must be maintained in the code, but there are many

other requirements in the code that contribute more to reduction of fire risk. Given that, one must

consider if public safety is better served by the current approach involving 3 separate tables, multiple

pressures, which result in different separation distances in different cases, OR is a single separation

distance a better approach.

This PI uses the basis developed originally and modified by the Task Group but selects a single

separation distance of 20 ft for all exposures for ease of application and enforcement. In some

cases, this approach is slightly more conservative than those achieved by the current method. In no case

is it less conservative. In all cases, it is greatly simpler to apply and enforce. In most cases, simpler is

better. This PI presents a simple option.

Material below is lifted from the substantiation developed by the current Separation Distance

Task Group:

Table 10.4.2.2.1(a) Minimum Distance (D) from Outdoor Bulk Hydrogen Compressed Gas

Systems to Exposures — Typical Maximum Pipe Size

Pressure > 15 to ≤ 250 psig

> 250 to ≤

3000 psig

> 3000 to≤

7500 psig

> 7500 to≤

15000 psig

Internal Pipe Diameter (ID)

>103.4 to≤

1724 kPa

>1724 to ≤

20,684 kPa

>20,684 to≤

51,711 kPa

>51,711 to≤

103,421 kPa


Group 1 Exposures m ft m ft m ft m ft

(a) Lot lines 125 4016 146 4620 94 2913 105 3416

(b) Air intakes (HVAC, compressors,

other)

(c) Operable openings in buildings and

structures

(d) Ignition sources such as open flames

and welding


(a) Exposed persons other than those

servicing the system

65 2016 76 2420 43 1310 54 1613

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(b) Parked cars


(a) Buildings of noncombustible non-fire-

rated construction 54 1713 65 1916 43 1210 44 1413


(c) Flammable gas storage systems above

or below ground

(d) Hazardous materials storage systems

above or below ground

(e) Heavy timber, coal, or other slow-

burning combustible solids

(f) Ordinary combustibles, including fast-

burning solids such as ordinary lumber,

excelsior, paper, or combustible waste and

vegetation other than that found in

maintained landscaped areas

(g) Unopenable openings in building and

structures

(h) Encroachment by overhead utilities

(horizontal distance from the vertical plane

below the nearest overhead electrical wire

of building service)

(i) Piping containing other hazardous

materials

(j) Flammable gas metering and regulating

stations such as natural gas or propane

Justification: There were three parameters identified in the analysis done to support the revised setback

distances that appeared in the 2010 edition of NFPA 55 that effectively determine the setback distances

for bulk gaseous hydrogen storage systems. These parameters are the heat flux harm criteria, the leak

area from the pipe that is the source of hydrogen, and the ignition concentration of hydrogen at which

sustained combustion occurs. The changes shown in this proposal are based on the proposed values

shown below. This justification statement will explain the rationale for revising these three parameters.

Parameter Existing Value from 2010 edition of NFPA 55

Proposed Value for 2019 edition of NFPA 55

Leak area (percent of pipe leak area)

3% 1%

Ignition concentration 4% hydrogen by volume 8% hydrogen by volume

Harm criteria 4.7 kW/m2 1.6 kW/m2

The analysis that forms the basis for the 2010 gaseous hydrogen setback distances is described in

“Analyses to Support Development of Risk-Informed Separation Distances for Hydrogen Codes and

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Standards “ (SAND2009-0874). The 2014 NFPA Task Group decided to revisit three of the risk criteria:

the leak area as a percent of the pipe diameter, the incident heat flux threshold, and the hydrogen

concentration threshold. The basis for reexamining these criteria was that since the 2010 edition of

NFPA 55 had been published there was considerably more experience with storage systems and

hydrogen fueling station performance. NREL, through its Technology Validation program has been

collecting data on hydrogen station performance since 2010. These data shows that there have not

been serious incidents involving hydrogen storage systems. These data are available for review at

http://www.nrel.gov/hydrogen/proj_infrastructure_analysis.html#cdp.

Leak Area Criteria

The cumulative probability for different leak sizes was calculated to determine what range of leaks

represents the most likely leak sizes. The system leakage frequency corresponds to the largest internal

pipe downstream of the highest-pressure source in the system. The results of this analysis indicated that

leaks less than 0.1 percent of the component flow areas represent 95 percent of the leakage frequency

for the example systems, however the risk resulting from this small leak size significantly exceeded the 2

x 10-5/yr. risk guideline set by the Task Group. At the same time, the use of a leak size between 1

percent and 10 percent of the component flow area results in risk estimates that are reasonably close to

the risk guideline. Table 1 shows the setback distances as function of various leak areas, radiant heat

fluxes and unignited jet concentration. This table appears as Table 3-3 in the SAND2009-0874 report.

Table 1. Harm Distances for Leak Areas, Harm Criteria, and Pressures [2]

Harm Criteria

Harm Distance (Leak Area)

>0.10 to 1.72 MPa (>15

to 250 psig)

>1.72 to 20.68 MPa

(>250 to 3000 psig)

>20.68 to 51.71 MPa

(>3000 to 7500 psig)

>51.71 to 103.43

MPa (>7500 to 15000

psig)

Un-ignited jet

concentration - 4%

mole fraction of

hydrogen

31.2 m (20% Area)

22.1 m (10% Area)

15.7 m (5% Area)

12.1 m (3% Area)

7.0 m (1% Area)

36.1 m (20% Area)

25.6 m (10% Area)

18.1 m (5% Area)

14.0 m (3% Area)

8.1 m (1% Area)

22.6 m (20% Area)

16.0 m (10% Area)

11.3 m (5% Area)

8.8 m (3% Area)

5.0 m (1% Area)

26.8 m (20% Area)

19.0 m (10% Area)

13.4 m (5% Area)

10.4 m (3% Area)

6.0 m (1% Area)

Radiation heat flux

level of 1.6 kW/m2

00(500 Btu/hr-ft2)

23.4 m (20% Area)

15.9 m (10% Area)

10.7 m (5% Area)

7.9 m (3% Area)

4.1 m (1% Area)

28.1 m (20% Area)

19.0 m (10% Area)

12.8 m (5% Area)

9.5 m (3% Area)

4.8 m (1% Area)

16.6 m (20% Area)

11.2 m (10% Area)

7.8 m (5% Area)

5.5 m (3% Area)

2.6 m (1% Area)

20.5 m (20% Area)

13.8 m (10% Area)

9.6 m (5% Area)

6.8 m (3% Area)

3.3 m (1% Area)

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Radiation heat flux

level of 4.7 kW/m2

(1500 Btu/hr-ft2)

17.0 m (20% Area)

11.6 m (10% Area)

7.9 m (5% Area)

5.9 m (3% Area)

3.1 m (1% Area)

20.2 m (20% Area)

13.8 m (10% Area)

9.4 m (5% Area)

7.0 m (3% Area)

3.7 m (1% Area)

12.2 m (20% Area)

8.2 m (10% Area)

5.5 m (5% Area)

4.1 m (3% Area)

2.1 m (1% Area)

14.9 m (20% Area)

10.0 m (10% Area)

6.7 m (5% Area)

5.1 m (3% Area)

2.6 m (1% Area)

Greater of radiation

heat flux level of

25237 W/m2 or

visible flame length1

13.0 m (20% Area)

9.2 m (10% Area)

6.5 m (5% Area)

5.0 m (3% Area)

2.9 m (1% Area)

15.0 m (20% Area)

10.6 m (10% Area)

7.5 m (5% Area)

5.8 m (3% Area)

3.4 m (1% Area)

9.4 m (20% Area)

6.7 m (10% Area)

4.7 m (5% Area)

3.6 m (3% Area)

2.1 m (1% Area)

11.1 m (20% Area)

7.9 m (10% Area)

5.6 m (5% Area)

4.3 m (3% Area)

2.5 m (1% Area)


heat flux level of

20000 W/m2 or


13.0 m (20% Area)

9.2 m (10% Area)

6.5 m (5% Area)

5.0 m (3% Area)

2.9 m (1% Area)

15.0 m (20% Area)

10.6 m (10% Area)

7.5 m (5% Area)

5.8 m (3% Area)

3.4 m (1% Area)

9.4 m (20% Area)

6.7 m (10% Area)

4.7 m (5% Area)

3.6 m (3% Area)

2.1 m (1% Area)

11.1 m (20% Area)

7.9 m (10% Area)

5.6 m (5% Area)

4.3 m (3% Area)

2.5 m (1% Area)

1The largest harm distances are predicted for the visible flame length.

Based on the results of both the system leakage frequency evaluation and the associated risk

assessment, the Task Group decided that adjusting to a diameter of 1 percent value, instead of a 3

percent, would remove excess conservatism from the input assumption to the model. The 1 percent

value still accounts for 95 percent of the leakage frequency from the example systems and does not

exceed the 2 x 10-5/year risk guideline established in the previous analysis. This results in more

permissive separation distance requirements with no change in risk.

Radiant Heat Flux Criteria

The Task Group also reviewed the heat flux values and determined that the use of a “no harm” criterion

(1.6 kW/m2) was overly conservative. This heat flux assumes exposed persons will not take protective

actions, such as moving away from the fire scene. The task group deemed it reasonable to assume that

exposed personnel will relocate away from a fire scene within a few minutes and therefore the “no harm”

criteria is not appropriate for establishing separation distances. Exposures that were analyzed based on

this heat flux value were updated to reflect the harm distance for a radiation heat flux level of 4.7 kW/m2.

The Task Group decided to not change the three other heat flux values used in the previous revision of the

separation distances in 2009.

Ignition Concentration Criteria

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The Task Group reviewed the hydrogen concentration threshold. Based on work done at Sandia

National Laboratories Combustion Research Facility, the Group concluded that there would not be

sustained ignition at hydrogen concentrations of 8% or less. There could be localized hydrogen ignition

that would not develop into sustained combustion. This point is demonstrated in the paper “Ignitability

limits for combustion of unintended hydrogen releases: Experimental and theoretical results” by R.W.

Schefer, et. al. This paper is available online at www.elsevier. Com/locate/he. Without getting into

great detail the paper states “Fig 4a shows that no flame light up can be achieved along the centerline

for XH2 ≤ 0.08 to 0.10”. The paper argues that no sustained combustion can be achieved below 10%

concentration. The selection of 8% concentration as the basis for revised setback distances reflects the

Task Group incorporating a measure of safety.

Calculating the Revised Setback Distances based on Revised Parameters

Most of the revised setback distances shown in the proposal had been calculated in the SAND2009-

0874 report because the setback distances for 1% leak area were calculated. However, a

methodology had to be developed to recalculate the distances for the n8% ignition concentration.

A correlation equation was used to determine hydrogen concentration, referenced in the SAND2009-

0874 report as Equation A.7, is given by:

�̅�𝑐𝑙(𝑥) = 𝐾𝑑𝑗

𝑥 + 𝑥𝑜(

𝜌∞

𝜌𝑔𝑎𝑠)

1/2

Where K is the entrainment constant, ρ∞ is the density of the ambient fluid, ρgas is the density of the

exiting gas evaluated at ambient temperature and pressure, x is the axial position, xo is the virtual origin

of the jet, dj is the jet exit diameter, and �̅�𝑐𝑙 is the mean volume fraction. This equation shows that the

mean mole fraction is inversely proportional to the distance (x) from the release, which makes the

distances exactly half as large when the mean mole fraction is doubled. Because all other parameters in

the equation are exactly the same, doubling the hydrogen concentration from 4% to 8% halves the

distances from the original table.

Based on these three proposals, a new version of the Table 3-3 that appeared in the SAND report was

created with updated values.

Table 2: Updated Values to the SAND2009-0874 Report

Harm Criteria Harm Distance (Leak Area)

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http://www.elsevier/

>0.10 to 1.72

MPa (>15 to 250

psig)

>1.72 to 20.68

MPa (>250 to

3000 psig)

>20.68 to 51.71

MPa (>3000 to

7500 psig)

>51.71 to 103.43

MPa (>7500 to

15000 psig)

Un-ignited jet

concentration - 8% mole

fraction of hydrogen

6.1 m (3% Area) 7.0 m (3% Area) 4.4 m (3% Area) 5.2 m (3% Area)


Radiation heat flux level

of 4.7 kW/m2 (1500

Btu/hr-ft2)




heat flux level of 25237

W/m2 or visible flame

length






length



Table 3 shows the revised separation distances for the four storage pressure ranges based on the task

group’s recommended changes in risk criteria. The safety distances in the table are also rounded to the

nearest whole number and multiplied by a 1.5 safety factor. To better understand how these numbers

are calculated, consider the Group 1 7500 to 15000 psig value of 5 meters. This number is the greater

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10.4.2.2 Location.

10.4.2.2.1* Minimum Distance.

The minimum distance from a bulk hydrogen compressed gas system located outdoors to the exposures specified below specified exposures shall be 20 ft. in accordance with Table 10.4.2.2.1(a), Table 10.4.2.2.1(b), or Table 10.4.2.2.1(c). (See also Annex G.)

(1) Lot lines (2) Air intakes (HVAC, compressors, other) (3) Operable openings in buildings and structures (4) Ignition sources such as open flames and welding (5) Exposed persons other than those servicing the system (6) Parked cars (7) Buildings of noncombustible non-fire-rated construction (8) Buildings of combustible construction (9) Flammable gas storage systems above or below ground (10) Hazardous materials storage systems above or below ground (11) Heavy timber, coal, or other slow-burning combustible solids (12) Ordinary combustibles, including fast-burning solids such as ordinary lumber, excelsior,

paper, or combustible waste and vegetation other than that found in maintained landscaped areas

(13) Unopenable openings in building and structures (14) Encroachment by overhead utilities (horizontal distance from the vertical plane below the

nearest overhead electrical wire of building service) (15) Piping containing other hazardous materials (16) Flammable gas metering and regulating stations such as natural gas or propane



Pressure > 15 to

≤250 psig

> 250 to

≤3000 psig

> 3000 to

≤7500 psig

> 7500 to

≤15,000 psig

Internal Pipe Diameter (ID) >103.4 to

≤1724 kPa

>1724 to

≤20,684 kPa

>20,684 to

≤51,711 kPa

>51,711 to

≤103,421 kPa



(a) Lot lines 12 40 14 46 9 29 10 34





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Pressure > 15 to

≤250 psig

> 250 to

≤3000 psig

> 3000 to

≤7500 psig

> 7500 to

≤15,000 psig

Internal Pipe Diameter (ID) >103.4 to

≤1724 kPa

>1724 to

≤20,684 kPa

>20,684 to

≤51,711 kPa

>51,711 to

≤103,421 kPa


(a) Exposed persons other than those servicing the system

6 20 7 24 4 13 5 16

(b) Parked cars


(a) Buildings of noncombustible non-fire-rated construction

5 17 6 19 4 12 4 14





(f) Ordinary combustibles, including fast-burning solids such as ordinary lumber, excelsior, paper, or combustible waste and vegetation other than that found in maintained landscaped areas


(h) Encroachment by overhead utilities (horizontal distance from the vertical plane below the nearest overhead electrical wire of building service)


(j) Flammable gas metering and regulating stations such as natural gas or propane

Table 10.4.2.2.1(b) Minimum Distance (D) from Outdoor Bulk Hydrogen Compressed Gas

Systems to Exposures by Maximum Pipe Size with Pressures >15 to ≤3000 psig

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>15 to ≤250 psig

.

>103.4 to ≤1724 kPa

>250 to ≤3000 psig .

>1724 to ≤20,684 kPa

Pressure Exposures*† Exposures*†

Internal Pipe

Diameter (ID) Group 1 Group 2 Group 3 Group 1 Group 2 Group 3

ID .

(in.)

d .

(mm)

D =

0.231d

D = 0.12584d -

0.47126

D =

0.096d

D =

0.738d

D = 0.43616d -

0.91791

D =

0.307d


0.2 5.1 1 4 0 1 0 2 4 12 1 4 2 5

0.3 7.6 2 6 0 2 1 2 6 18 2 8 2 8

0.4 10.2 2 8 1 3 1 3 7 25 4 12 3 10

0.5 12.7 3 10 1 4 1 4 9 31 5 15 4 13

0.6 15.2 4 12 1 5 1 5 11 37 6 19 5 15

0.7 17.8 4 13 2 6 2 6 13 43 7 22 5 18

0.8 20.3 5 15 2 7 2 6 15 49 8 26 6 20

0.9 22.9 5 17 2 8 2 7 17 55 9 30 7 23

1.0 25.4 6 19 3 9 2 8 19 62 10 33 8 26

1.1 27.9 6 21 3 10 3 9 21 68 11 37 9 28

1.2 30.5 7 23 3 11 3 10 22 74 12 41 9 31

1.3 33.0 8 25 4 12 3 10 24 80 13 44 10 33

1.4 35.6 8 27 4 13 3 11 26 86 15 48 11 36

1.5 38.1 9 29 4 14 4 12 28 92 16 52 12 38

1.6 40.6 9 31 5 15 4 13 30 98 17 55 12 41

1.7 43.2 10 33 5 16 4 14 32 105 18 59 13 43

1.8 45.7 11 35 5 17 4 14 34 111 19 62 14 46

1.9 48.3 11 37 6 18 5 15 36 117 20 66 15 49

2.0 50.8 12 39 6 19 5 16 37 123 21 70 16 51

2.1 53.3 12 40 6 20 5 17 39 129 22 73 16 54


*For a list of exposures in each exposure group see Column 1 of Table 10.4.2.2.1(a).

†When calculating the minimum separation distance (D) using the formulas indicated, based on the exposure group and pressure indicated, the internal pipe diameter (d) is entered in millimeters (mm). The calculated distance (D) is expressed in units of measure in meters (m). To convert distance (D)

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to units of measure in feet, multiply the value of (D) in meters by 3.2808 and round to the nearest whole foot.

Table 10.4.2.2.1(c) Minimum Distance (D) from Outdoor Bulk Hydrogen Compressed Gas

Systems to Exposures by Maximum Pipe Size with Pressures >3000 to ≤15,000 psig

>3000 to ≤7500 psig

.

>20,684 to ≤51,711 kPa

>7500 to ≤15,000 psig .

>51,711 to ≤103,421 kPa


Internal Pipe

Diameter (ID) Group 1 Group 2 Group 3 Group 1 Group 2 Group 3

ID .

(in.)

d .

(mm)

D =

1.105d

D = 0.68311d -

1.3123

D =

0.459d

D =

1.448d

D = 0.92909d -

1.6813

D =

0.602d


0.2 5.1 6 18 2 7 2 8 7 24 3 10 3 10

0.3 7.6 8 28 4 13 3 11 11 36 5 18 5 15

0.4 10.2 11 37 6 18 5 15 15 48 8 25 6 20

0.5 12.7 14 46 7 24 6 19 18 60 10 33 8 25

0.6 15.2 17 55 9 30 7 23 22 72 12 41 9 30

0.7 17.8 20 64 11 36 8 27 26 84 15 49 11 35

0.8 20.3 22 74 13 41 9 31 29 97 17 56 12 40

0.9 22.9 25 83 14 47 10 34 33 109 20 64 14 45

1.0 25.4 28 92 16 53 12 38 37 121 22 72 15 50

1.1 27.9 31 101 18 58 13 42 40 133 24 80 17 55

1.2 30.5 34 111 20 64 14 46 44 145 27 87 18 60

1.3 33.0 36 120 21 70 15 50 48 157 29 95 20 65

1.4 35.6 39 129 23 75 16 54 51 169 31 103 21 70

1.5 38.1 42 138 25 81 17 57 55 181 34 111 23 75

1.6 40.6 45 147 26 87 19 61 59 193 36 118 24 80

1.7 43.2 48 157 28 92 20 65 63 205 38 126 26 85

1.8 45.7 51 166 30 98 21 69 66 217 41 134 28 90

1.9 48.3 53 175 32 104 22 73 70 229 43 142 29 95

2.0 50.8 56 184 33 110 23 77 74 241 46 149 31 100


*For a list of exposures in each exposure group see Column 1 of Table 10.3.2.1(a).

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10.4.2.2.1.1

The separation distance for piping systems with internal diameters other than those specified in Table 10.4.2.2.1(a) for the pressure range selected shall be permitted with tabular distances determined based on the use of Table 10.4.2.2.1(b) or Table 10.4.2.2.1(c).

10.4.2.2.2 Maximum Internal Diameter of Interconnecting Piping.

The maximum internal diameter of the piping system used for interconnecting piping between the shutoff valve on any single storage container to the point of connection to the system source valve shall not be required to be in accordance with the values shown in Table 10.4.2.2.1(a) when in accordance with Table 10.4.2.2.1(b) or Table 10.4.2.2.1(c).

10.4.2.2.2.1* Determination of Internal Diameter.

The internal diameter of the piping system shall be determined by the diameter of the piping serving that portion of a storage array with content greater than 5000 scf (141.6 Nm3). The piping system size used in the application of Table 10.4.2.2.1(a), Table 10.4.2.2.1(b), or Table 10.4.2.2.1(c) shall be determined based on that portion of the system with the greatest maximum internal diameter.

10.4.2.2.2.2

Separation distances determined based on the use of Table 10.4.2.2.1(b) or Table 10.4.2.2.1(c) shall be subject to review and approval by the AHJ.

10.4.2.2.3*

Determination of System Pressure. The system pressure shall be determined by the maximum operating pressure of the storage array with content greater than 5000 scf (141.6 Nm3), irrespective of those portions of the system elevated to a higher pressure.

10.4.2.2.4* Reduction of Distance by Mitigation Means.

10.4.2.2.4.1* Passive Means.

Except for The distances to air intakes, the distances to Group 1 and 2 exposures 1, 3, 4, 5, and 6 in 10.4.2.2.1 shown in Table 10.4.2.2.1(a), Table 10.4.2.2.1(b), and Table 10.4.2.2.1(c) shall be permitted to be reduced by one-half and shall not apply to exposures 7 through 16 in 10.4.2.2.1 Group 3 exposures where fire barrier walls are located between the system and the exposure and constructed in accordance with the following:


(2) The fire barrier wall shall interrupt the line of sight between the bulk hydrogen compressed gas system and the exposure.

(3) The configuration of the fire barrier shall allow natural ventilation to prevent the accumulation of hazardous gas concentrations.

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(5) The fire barrier wall shall not have more than two sides at 90 degrees (1.57 rad) directions or not more than three sides with connecting angles of 135 degrees (2.36 rad).

(a) *The connecting angles between fire barrier walls shall be permitted to be reduced to less than 135 degrees (2.36 rad) for installations consisting of three walls when in accordance with 8.13.2.7.2.

(6) Fire barrier walls shall be designed and constructed as a structure in accordance with the requirements of the building code without exceeding the specified allowable stresses for the materials of construction utilized. Structures shall be designed to resist the overturning effects caused by lateral forces due to wind, soil, flood, and seismic events.

(7) Where clearance is required between the bulk hydrogen compressed gas system and the barrier wall for the performance of service or maintenance-related activities, a minimum horizontal clearance of 5 ft (1.5 m) shall be provided between the structure and the system.

(8) The fire barrier wall shall be either an independent structure or the exterior wall of the building adjacent to the storage or use area when the exterior building wall meets the requirements for fire barrier walls. 10.4.2.2.4.2 The distance reduction allowed by 10.4.2.2.4.1 shall not apply to air intakes.

10.4.2.2.4.32* Active Means.

Active control systems that mitigate the risk of system leaks and failures shall be permitted to be used as a means to reduce separation distances where approved by the AHJ under the authority as granted by Section 1.5.

10.4.2.2.5 Required Separation Distances for All Systems.

Separation distances shall be required for bulk hydrogen compressed gas systems independent of system pressure or internal diameter of piping systems in accordance with 10.4.2.2.5.1 through 10.4.2.2.5.3.

10.4.2.2.5.1

Unloading connections on delivery equipment shall not be positioned closer to any of be separated from the exposures cited in10.4.2.2.1 by not less than 20 ft. Table 10.4.2.2.1(a), Table 10.4.2.2.1(b), or Table 10.4.2.2.1(c) than the distances given for the storage system.

10.4.2.2.5.2

The minimum separation distance between gaseous and liquid systems integrated into a single system where the liquid source is vaporized, compressed, and stored in the gaseous state shall be 15 ft (4.6 m).

10.4.2.2.5.3

Systems within 50 ft (15 m) of aboveground storage of all classes of flammable and combustible liquids shall be located on ground higher than such storage, except where dikes, diversion curbs, grading, or separating solid walls are used to prevent accumulation of these liquids under the system.

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of the unignited jet setback distance (3 meters) and the radiant heat flux distance (2.6 meters) shown

in Table 2 multiplied by a safety factor of 1.5. Therefore, the table value is 3 meters times a 1.5 safety

factor or 4.5 meters. This number was rounded up to 5 meters. The 1.5 safety factor was used by the

Task Group because it is a commonly used safety factor in industrial gas system design.

Table 3. Draft Proposed Values to 2 NFPA 55 Tables with 1.5 Safety Factor

Exposures

Separation Distance

>0.10 to 1.7 MPa

(>15 to 250 psig)

>1.7 to 20.7 MPa

(>250 to 3000 psig)

>20.7 to 51.7 MPa

(>3000 to 7500 psig)

51.7 to 103.4 MPa

(7500 to 15000 psig)

Group

1 Existing 12 m (40 ft) 14 m (46 ft) 9 m (29 ft) 10 m (34 ft)

Proposed

New 5 m (16 ft) 6 m (20 ft) 4 m (13 ft) 5 m (16 ft)

Group


Proposed


Group


Proposed


Group 1 Exposures include: lot lines, air intakes, operable openings in buildings and structures, and

ignition sources. Group 1 separation distances are based on the higher value of radiation heat flux of

4.7kW/m2 or the unignited jet concentration decay distance of 8% hydrogen volume fraction

concentration. In this instance, the separation distance is higher for the concentration value than the

heat flux value so the change in the heat flux value does not impact these distances. It should be noted

that these Group 1 distances are typically the critical distances in determining whether a hydrogen

storage system can be located at a specific site.

Group 2 Exposures include: parked cars, exposed persons other than those servicing the system. Group

2 separation distances are based on the higher value of the incident radiation heat flux of 4.7kW/m2

exposure to employees for a maximum of 3 minutes or the visible flame length.

Group 3 Exposures includes everything else (ex: buildings of combustible construction, ordinary

combustibles, openings in buildings and structures, etc.). Group 3 separation distances are based on the

higher value of the radiant heat flux for non-combustible equipment of 25.2 kW/m2 or the visible flame

length.

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Public Input No. 53-NFPA 55-2016 [ Section No. 10.4.2.2.1 [Excluding any Sub-Sections]

]


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The minimum distance from a bulk hydrogen compressed gas system located outdoors to specifiedexposures shall be in accordance with Table 10.4.2.2.1(a) , Table 10.4.2.2.1(b) , or Table 10.4.2.2.1(c) .(See also Annex G.)

Table 10.4.2.2.1(a) Minimum Distance (D) from Outdoor Bulk Hydrogen Compressed Gas Systems toExposures — Typical Maximum Pipe Size

Pressure > 15 to≤250 psig

> 250 to≤3000 psig

> 3000 to≤7500 psig

> 7500 to≤15,000 psig

Internal Pipe Diameter (ID) >103.4 to≤1724 kPa

>1724 to≤20,684 kPa

>20,684 to≤51,711 kPa

>51,711 to≤103,421 kPa



(a) Lot lines 12 40 14 46 9 29 10 34


(c) Operable openings in buildings andstructures

(d) Ignition sources such as open flamesand welding


(a) Exposed persons other than thoseservicing the system

6 20 7 24 4 13 5 16

(b) Parked cars


(a) Buildings of noncombustiblenon-fire-rated construction

5 17 6 19 4 12 4 14


(c) Flammable gas storage systems aboveor below ground

(d) Hazardous materials storage systemsabove or below ground

(e) Heavy timber, coal, or otherslow-burning combustible solids

(f) Ordinary combustibles, includingfast-burning solids such as ordinary lumber,excelsior, paper, or combustible waste andvegetation other than that found inmaintained landscaped areas

(g) Unopenable openings in building andstructures

(h) Encroachment by overhead utilities(horizontal distance from the vertical planebelow the nearest overhead electrical wireof building service)

(i) Piping containing other hazardousmaterials

(j) Flammable gas metering and regulatingstations such as natural gas or propane

Table 10.4.2.2.1(b) Minimum Distance (D) from Outdoor Bulk Hydrogen Compressed Gas Systems toExposures by Maximum Pipe Size with Pressures >15 to ≤3000 psig

>15 to ≤250 psig

>103.4 to ≤1724 kPa

>250 to ≤3000 psig

>1724 to ≤20,684 kPa


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ID

(in.)

d

(mm)

D =0.231d

D = 0.12584d -0.47126

D =0.096d

D =0.738d

D = 0.43616d -0.91791

D =0.307d


0.2 5.1 1 4 0 1 0 2 4 12 1 4 2 5

0.3 7.6 2 6 0 2 1 2 6 18 2 8 2 8

0.4 10.2 2 8 1 3 1 3 7 25 4 12 3 10

0.5 12.7 3 10 1 4 1 4 9 31 5 15 4 13

0.6 15.2 4 12 1 5 1 5 11 37 6 19 5 15

0.7 17.8 4 13 2 6 2 6 13 43 7 22 5 18

0.8 20.3 5 15 2 7 2 6 15 49 8 26 6 20

0.9 22.9 5 17 2 8 2 7 17 55 9 30 7 23

1.0 25.4 6 19 3 9 2 8 19 62 10 33 8 26

1.1 27.9 6 21 3 10 3 9 21 68 11 37 9 28

1.2 30.5 7 23 3 11 3 10 22 74 12 41 9 31

1.3 33.0 8 25 4 12 3 10 24 80 13 44 10 33

1.4 35.6 8 27 4 13 3 11 26 86 15 48 11 36

1.5 38.1 9 29 4 14 4 12 28 92 16 52 12 38

1.6 40.6 9 31 5 15 4 13 30 98 17 55 12 41

1.7 43.2 10 33 5 16 4 14 32 105 18 59 13 43

1.8 45.7 11 35 5 17 4 14 34 111 19 62 14 46

1.9 48.3 11 37 6 18 5 15 36 117 20 66 15 49

2.0 50.8 12 39 6 19 5 16 37 123 21 70 16 51

2.1 53.3 12 40 6 20 5 17 39 129 22 73 16 54


*For a list of exposures in each exposure group see Column 1 of Table 10.4.2.2.1(a).

†When calculating the minimum separation distance (D) using the formulas indicated, based on theexposure group and pressure indicated, the internal pipe diameter (d) is entered in millimeters (mm). Thecalculated distance (D) is expressed in units of measure in meters (m). To convert distance (D) to units ofmeasure in feet, multiply the value of (D) in meters by 3.2808 and round to the nearest whole foot.

Table 10.4.2.2.1(c) Minimum Distance (D) from Outdoor Bulk Hydrogen Compressed Gas Systems toExposures by Maximum Pipe Size with Pressures >3000 to ≤15,000 psig

>3000 to ≤7500 psig

>20,684 to ≤51,711 kPa

>7500 to ≤15,000 psig

>51,711 to ≤103,421 kPa




ID

(in.)

d

(mm)

D =1.105d

D = 0.68311d -1.3123

D =0.459d

D =1.448d

D = 0.92909d -1.6813

D =0.602d


0.2 5.1 6 18 2 7 2 8 7 24 3 10 3 10

0.3 7.6 8 28 4 13 3 11 11 36 5 18 5 15


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>3000 to ≤7500 psig

>20,684 to ≤51,711 kPa

>7500 to ≤15,000 psig

>51,711 to ≤103,421 kPa




ID

(in.)

d

(mm)

D =1.105d

D = 0.68311d -1.3123

D =0.459d

D =1.448d

D = 0.92909d -1.6813

D =0.602d


0.4 10.2 11 37 6 18 5 15 15 48 8 25 6 20

0.5 12.7 14 46 7 24 6 19 18 60 10 33 8 25

0.6 15.2 17 55 9 30 7 23 22 72 12 41 9 30

0.7 17.8 20 64 11 36 8 27 26 84 15 49 11 35

0.8 20.3 22 74 13 41 9 31 29 97 17 56 12 40

0.9 22.9 25 83 14 47 10 34 33 109 20 64 14 45

1.0 25.4 28 92 16 53 12 38 37 121 22 72 15 50

1.1 27.9 31 101 18 58 13 42 40 133 24 80 17 55

1.2 30.5 34 111 20 64 14 46 44 145 27 87 18 60

1.3 33.0 36 120 21 70 15 50 48 157 29 95 20 65

1.4 35.6 39 129 23 75 16 54 51 169 31 103 21 70

1.5 38.1 42 138 25 81 17 57 55 181 34 111 23 75

1.6 40.6 45 147 26 87 19 61 59 193 36 118 24 80

1.7 43.2 48 157 28 92 20 65 63 205 38 126 26 85

1.8 45.7 51 166 30 98 21 69 66 217 41 134 28 90

1.9 48.3 53 175 32 104 22 73 70 229 43 142 29 95

2.0 50.8 56 184 33 110 23 77 74 241 46 149 31 100


*For a list of exposures in each exposure group see Column 1 of Table 10.3.2.1(a).

†When calculating the minimum separation distance (D) using the formulas indicated, based on theexposure group and pressure indicated, the internal pipe diameter (d) is entered in millimeters (mm). Thecalculated distance (D) is expressed in units of measure in meters (m). To convert distance (D) to units ofmeasure in feet, multiply the value of (D) in meters by 3.2808 and round to the nearest whole foot.



Proposal_to_Modify_Setback_Distances_for_Bulk_Gaseous_Hydrogen_Storage_June2016.docx

Revise Table 10.4.2.2.1 (a)


The setback distances are in Table 10.4.2.2.1.(a) do not reflect deployment information that has been accrued since the 2010 revision of these distances. This proposal incorporates the latest information and analysis. This proposal reflects over two years of work of the NFPA hydrogen Storage Task Group. See earlier file attachment for substantiation.



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Submitter Full Name: Carl Rivkin

Organization: National Renewable Energy Labo

Street Address:

City:

State:

Zip:



88 of 122 7/13/2016 10:38 AM

703 of 745

Proposal to Modify Setback Distances for Bulk Gaseous Hydrogen Storage



Pressure > 15 to ≤ 250 psig

> 250 to ≤

3000 psig

> 3000 to≤

7500 psig

> 7500 to≤

15000 psig

Internal Pipe Diameter (ID)

>103.4 to≤

1724 kPa

>1724 to ≤

20,684 kPa

>20,684 to≤

51,711 kPa

>51,711 to≤

103,421 kPa



(a) Lot lines 125 4016 146 4620 94 2913 105 3416

(b) Air intakes (HVAC, compressors,

other)

(c) Operable openings in buildings and

structures

(d) Ignition sources such as open flames

and welding


(a) Exposed persons other than those

servicing the system 65 2016 76 2420 43 1310 54 1613

(b) Parked cars


(a) Buildings of noncombustible non-fire-

rated construction

54 1713 65 1916 43 1210 44 1413


(c) Flammable gas storage systems above

or below ground

(d) Hazardous materials storage systems

above or below ground

(e) Heavy timber, coal, or other slow-

burning combustible solids

(f) Ordinary combustibles, including fast-

burning solids such as ordinary lumber,

excelsior, paper, or combustible waste and

vegetation other than that found in

maintained landscaped areas

(g) Unopenable openings in building and

structures

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(h) Encroachment by overhead utilities

(horizontal distance from the vertical plane

below the nearest overhead electrical wire

of building service)

(i) Piping containing other hazardous

materials

(j) Flammable gas metering and regulating

stations such as natural gas or propane

Justification: There were three parameters identified in the analysis done to support the revised setback

distances that appeared in the 2010 edition of NFPA 55 that effectively determine the setback distances

for bulk gaseous hydrogen storage systems. These parameters are the heat flux harm criteria, the leak

area from the pipe that is the source of hydrogen, and the ignition concentration of hydrogen at which

sustained combustion occurs. The changes shown in this proposal are based on the proposed values

shown below. This justification statement will explain the rationale for revising these three parameters.

Parameter Existing Value from 2010 edition of NFPA 55

Proposed Value for 2019 edition of NFPA 55

Leak area (percent of pipe leak area)

3% 1%

Ignition concentration 4% hydrogen by volume 8% hydrogen by volume

Harm criteria 4.7 kW/m2 1.6 kW/m2

The analysis that forms the basis for the 2010 gaseous hydrogen setback distances is described in

“Analyses to Support Development of Risk-Informed Separation Distances for Hydrogen Codes and

Standards “ (SAND2009-0874). The 2014 NFPA Task Group decided to revisit three of the risk criteria:

the leak area as a percent of the pipe diameter, the incident heat flux threshold, and the hydrogen

concentration threshold. The basis for reexamining these criteria was that since the 2010 edition of

NFPA 55 had been published there was considerably more experience with storage systems and

hydrogen fueling station performance. NREL, through its Technology Validation program has been

collecting data on hydrogen station performance since 2010. These data shows that there have not

been serious incidents involving hydrogen storage systems. These data are available for review at

http://www.nrel.gov/hydrogen/proj_infrastructure_analysis.html#cdp.

Leak Area Criteria

The cumulative probability for different leak sizes was calculated to determine what range of leaks

represents the most likely leak sizes. The system leakage frequency corresponds to the largest internal

pipe downstream of the highest-pressure source in the system. The results of this analysis indicated that

leaks less than 0.1 percent of the component flow areas represent 95 percent of the leakage frequency

for the example systems, however the risk resulting from this small leak size significantly exceeded the 2

x 10-5/yr. risk guideline set by the Task Group. At the same time, the use of a leak size between 1

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percent and 10 percent of the component flow area results in risk estimates that are reasonably close to

the risk guideline. Table 1 shows the setback distances as function of various leak areas, radiant heat

fluxes and unignited jet concentration. This table appears as Table 3-3 in the SAND2009-0874 report.

Table 1. Harm Distances for Leak Areas, Harm Criteria, and Pressures [2]

Harm Criteria


>0.10 to 1.72 MPa (>15

to 250 psig)

>1.72 to 20.68 MPa

(>250 to 3000 psig)

>20.68 to 51.71 MPa

(>3000 to 7500 psig)

>51.71 to 103.43

MPa (>7500 to 15000

psig)

Un-ignited jet

concentration - 4%

mole fraction of

hydrogen

31.2 m (20% Area)

22.1 m (10% Area)

15.7 m (5% Area)

12.1 m (3% Area)

7.0 m (1% Area)

36.1 m (20% Area)

25.6 m (10% Area)

18.1 m (5% Area)

14.0 m (3% Area)

8.1 m (1% Area)

22.6 m (20% Area)

16.0 m (10% Area)

11.3 m (5% Area)

8.8 m (3% Area)

5.0 m (1% Area)

26.8 m (20% Area)

19.0 m (10% Area)

13.4 m (5% Area)

10.4 m (3% Area)

6.0 m (1% Area)

Radiation heat flux

level of 1.6 kW/m2

00(500 Btu/hr-ft2)

23.4 m (20% Area)

15.9 m (10% Area)

10.7 m (5% Area)

7.9 m (3% Area)

4.1 m (1% Area)

28.1 m (20% Area)

19.0 m (10% Area)

12.8 m (5% Area)

9.5 m (3% Area)

4.8 m (1% Area)

16.6 m (20% Area)

11.2 m (10% Area)

7.8 m (5% Area)

5.5 m (3% Area)

2.6 m (1% Area)

20.5 m (20% Area)

13.8 m (10% Area)

9.6 m (5% Area)

6.8 m (3% Area)

3.3 m (1% Area)

Radiation heat flux

level of 4.7 kW/m2

(1500 Btu/hr-ft2)

17.0 m (20% Area)

11.6 m (10% Area)

7.9 m (5% Area)

5.9 m (3% Area)

3.1 m (1% Area)

20.2 m (20% Area)

13.8 m (10% Area)

9.4 m (5% Area)

7.0 m (3% Area)

3.7 m (1% Area)

12.2 m (20% Area)

8.2 m (10% Area)

5.5 m (5% Area)

4.1 m (3% Area)

2.1 m (1% Area)

14.9 m (20% Area)

10.0 m (10% Area)

6.7 m (5% Area)

5.1 m (3% Area)

2.6 m (1% Area)


heat flux level of

25237 W/m2 or


13.0 m (20% Area)

9.2 m (10% Area)

6.5 m (5% Area)

5.0 m (3% Area)

2.9 m (1% Area)

15.0 m (20% Area)

10.6 m (10% Area)

7.5 m (5% Area)

5.8 m (3% Area)

3.4 m (1% Area)

9.4 m (20% Area)

6.7 m (10% Area)

4.7 m (5% Area)

3.6 m (3% Area)

2.1 m (1% Area)

11.1 m (20% Area)

7.9 m (10% Area)

5.6 m (5% Area)

4.3 m (3% Area)

2.5 m (1% Area)


heat flux level of

20000 W/m2 or


13.0 m (20% Area)

9.2 m (10% Area)

6.5 m (5% Area)

5.0 m (3% Area)

2.9 m (1% Area)

15.0 m (20% Area)

10.6 m (10% Area)

7.5 m (5% Area)

5.8 m (3% Area)

3.4 m (1% Area)

9.4 m (20% Area)

6.7 m (10% Area)

4.7 m (5% Area)

3.6 m (3% Area)

2.1 m (1% Area)

11.1 m (20% Area)

7.9 m (10% Area)

5.6 m (5% Area)

4.3 m (3% Area)

2.5 m (1% Area)

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1The largest harm distances are predicted for the visible flame length.

Based on the results of both the system leakage frequency evaluation and the associated risk

assessment, the Task Group decided that adjusting to a diameter of 1 percent value, instead of a 3

percent, would remove excess conservatism from the input assumption to the model. The 1 percent

value still accounts for 95 percent of the leakage frequency from the example systems and does not

exceed the 2 x 10-5/year risk guideline established in the previous analysis. This results in more

permissive separation distance requirements with no change in risk.

Radiant Heat Flux Criteria

The Task Group also reviewed the heat flux values and determined that the use of a “no harm” criterion

(1.6 kW/m2) was overly conservative. This heat flux assumes exposed persons will not take protective

actions, such as moving away from the fire scene. The task group deemed it reasonable to assume that

exposed personnel will relocate away from a fire scene within a few minutes and therefore the “no harm”

criteria is not appropriate for establishing separation distances. Exposures that were analyzed based on

this heat flux value were updated to reflect the harm distance for a radiation heat flux level of 4.7 kW/m2.

The Task Group decided to not change the three other heat flux values used in the previous revision of the

separation distances in 2009.

Ignition Concentration Criteria

The Task Group reviewed the hydrogen concentration threshold. Based on work done at Sandia

National Laboratories Combustion Research Facility, the Group concluded that there would not be

sustained ignition at hydrogen concentrations of 8% or less. There could be localized hydrogen ignition

that would not develop into sustained combustion. This point is demonstrated in the paper “Ignitability

limits for combustion of unintended hydrogen releases: Experimental and theoretical results” by R.W.

Schefer, et. al. This paper is available online at www.elsevier. Com/locate/he. Without getting into

great detail the paper states “Fig 4a shows that no flame light up can be achieved along the centerline

for XH2 ≤ 0.08 to 0.10”. The paper argues that no sustained combustion can be achieved below 10%

concentration. The selection of 8% concentration as the basis for revised setback distances reflects the

Task Group incorporating a measure of safety.

Calculating the Revised Setback Distances based on Revised Parameters

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http://www.elsevier/

Most of the revised setback distances shown in the proposal had been calculated in the SAND2009-

0874 report because the setback distances for 1% leak area were calculated. However, a

methodology had to be developed to recalculate the distances for the n8% ignition concentration.

A correlation equation was used to determine hydrogen concentration, referenced in the SAND2009-

0874 report as Equation A.7, is given by:

�̅�𝑐𝑙(𝑥) = 𝐾𝑑𝑗

𝑥 + 𝑥𝑜(

𝜌∞

𝜌𝑔𝑎𝑠)

1/2

Where K is the entrainment constant, ρ∞ is the density of the ambient fluid, ρgas is the density of the

exiting gas evaluated at ambient temperature and pressure, x is the axial position, xo is the virtual origin

of the jet, dj is the jet exit diameter, and �̅�𝑐𝑙 is the mean volume fraction. This equation shows that the

mean mole fraction is inversely proportional to the distance (x) from the release, which makes the

distances exactly half as large when the mean mole fraction is doubled. Because all other parameters in

the equation are exactly the same, doubling the hydrogen concentration from 4% to 8% halves the

distances from the original table.

Based on these three proposals, a new version of the Table 3-3 that appeared in the SAND report was

created with updated values.

Table 2: Updated Values to the SAND2009-0874 Report

Harm Criteria


>0.10 to 1.72

MPa (>15 to 250

psig)

>1.72 to 20.68

MPa (>250 to

3000 psig)

>20.68 to 51.71

MPa (>3000 to

7500 psig)

>51.71 to 103.43

MPa (>7500 to

15000 psig)

Un-ignited jet

concentration - 8% mole

fraction of hydrogen



Radiation heat flux level

of 4.7 kW/m2 (1500

Btu/hr-ft2)






length



Greater of radiation 5.0 m (3% Area) 5.8 m (3% Area) 3.6 m (3% Area) 4.3 m (3% Area)

708 of 745



length 2.9 m (1% Area) 3.4 m (1% Area) 2.1 m (1% Area) 2.5 m (1% Area)

Table 3 shows the revised separation distances for the four storage pressure ranges based on the task

group’s recommended changes in risk criteria. The safety distances in the table are also rounded to the

nearest whole number and multiplied by a 1.5 safety factor. To better understand how these numbers

are calculated, consider the Group 1 7500 to 15000 psig value of 5 meters. This number is the greater

of the unignited jet setback distance (3 meters) and the radiant heat flux distance (2.6 meters) shown

in Table 2 multiplied by a safety factor of 1.5. Therefore, the table value is 3 meters times a 1.5 safety

factor or 4.5 meters. This number was rounded up to 5 meters. The 1.5 safety factor was used by the

Task Group because it is a commonly used safety factor in industrial gas system design.

Table 3. Draft Proposed Values to 2 NFPA 55 Tables with 1.5 Safety Factor

Exposures

Separation Distance

>0.10 to 1.7 MPa

(>15 to 250 psig)

>1.7 to 20.7 MPa

(>250 to 3000 psig)

>20.7 to 51.7 MPa

(>3000 to 7500 psig)

51.7 to 103.4 MPa

(7500 to 15000 psig)

Group


Proposed


Group


Proposed 5 m (16 ft) 6 m (20 ft) 3 m (10 ft) 4 m (13 ft)

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New

Group


Proposed


Group 1 Exposures include: lot lines, air intakes, operable openings in buildings and structures, and

ignition sources. Group 1 separation distances are based on the higher value of radiation heat flux of

4.7kW/m2 or the unignited jet concentration decay distance of 8% hydrogen volume fraction

concentration. In this instance, the separation distance is higher for the concentration value than the

heat flux value so the change in the heat flux value does not impact these distances. It should be noted

that these Group 1 distances are typically the critical distances in determining whether a hydrogen

storage system can be located at a specific site.

Group 2 Exposures include: parked cars, exposed persons other than those servicing the system. Group

2 separation distances are based on the higher value of the incident radiation heat flux of 4.7kW/m2

exposure to employees for a maximum of 3 minutes or the visible flame length.

Group 3 Exposures includes everything else (ex: buildings of combustible construction, ordinary

combustibles, openings in buildings and structures, etc.). Group 3 separation distances are based on the

higher value of the radiant heat flux for non-combustible equipment of 25.2 kW/m2 or the visible flame

length.

710 of 745


10.4.2.2.1.1

The distance shall be measured from the part of the bulk hydrogen compressed gas system closest to theexposure.


The NFPA 2 / 55 hydrogen separations task group found a gap in the code where there is no specific guidance on measuring exposure distances.



Organization: CGA

Street Address:

City:

State:

Zip:



89 of 122 7/13/2016 10:38 AM

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10.4.2.2.4.1* Passive Means.

Except for distances to air intakes, the distances to Group 1 and 2 exposures shown in Table 10.4.2.2.1(a),Table 10.4.2.2.1(b) , and Table 10.4.2.2.1(c) shall be permitted to be reduced by one-half, and shall notapply the distances to Group 3 exposures shall be permitted to be reduced to 5ft (1.5 m) where firebarrier walls are located between the system and the exposure and constructed in accordance with thefollowing:


(2) The fire barrier wall shall interrupt the line of sight between the bulk hydrogen compressed gas systemand the exposure.

(3) The configuration of the fire barrier shall allow natural ventilation to prevent the accumulation ofhazardous gas concentrations.


(5) The fire barrier wall shall not have more than two sides at 90 degrees (1.57 rad) directions or not morethan three sides with connecting angles of 135 degrees (2.36 rad).

(6)

(7) Fire barrier walls shall be designed and constructed as a structure in accordance with therequirements of the building code without exceeding the specified allowable stresses for the materialsof construction utilized. Structures shall be designed to resist the overturning effects caused by lateralforces due to wind, soil, flood, and seismic events.

(8) Where clearance is required between the bulk hydrogen compressed gas system and the barrier wallfor the performance of service or maintenance-related activities, a minimum horizontal clearance of 5 ft(1.5 m) shall be provided between the structure and the system.

(9) The fire barrier wall shall be either an independent structure or the exterior wall of the buildingadjacent to the storage or use area when the exterior building wall meets the requirements for firebarrier walls.


In section 10.4.2.2.4.1, the existing wording is not clear about the impact of firewalls on the group 3 exposures. The existing language states (shortened with some wording removed for simplicity) “the distances to Group 1 and 2 exposures… shall not apply to Group 3 exposures where fire barrier walls are located…” The intent is to say that the group 3 exposure distances do not apply where fire barrier walls are used. However, the language says that the group 1 and 2 exposure distances do not apply to group 3 exposures. The new language removes the confusion by stating that the group 3 exposure distances can be reduced to 5 ft when a fire barrier wall is used.

5 ft was added to provide a requirement for room between the exposure and the fire barrier wall to be consistent with the general requirements in chapter 8:

8.7.2.1.3 The fire barrier wall shall be located not less than 5 ft (1.5 m) from any exposure.

The reasoning for separation between the fire barrier wall and the hydrogen system also applies to the separation between the exposure and the fire barrier wall.


* The connecting angles between fire barrier walls shall be permitted to be reduced to lessthan 135 degrees (2.36 rad) for installations consisting of three walls when in accordance with8.13.2.7.2 .


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10.4.5.1.1

The location of bulk hydrogen compressed gas systems shall be in accordance with Table 10.4.5.1.1.

Table 10.4.5.1.1 Location of Bulk Hydrogen Compressed Gas Systems

Quantity of Hydrogen

Location

≥5000 to <15,000scf

(≥142 to

<425 Nm3)

≥15,000 scf

(≥425 Nm3)

In a detached building A A

In a gas room, Protection Level 2 occupancy in accordance withSection 6.4 Section 6.3.2

ADetached buildingrequired

Not in a gas room Protection Level 2 occupancy NADetached buildingrequired



Gas Rooms are OK to double the MAQ but 15,000 cu ft is far in excess of that. However, the requirements for detached building is a good one and should be retained because without this limit the amount of flammable gas in a PL-2 occupancy would be unlimited.




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10 6 .4. 5.3 Hydrogen Gas Rooms.

10 6 .4. 5.3. 1

Floors, walls, and ceilings shall be constructed of noncombustible or limited-combustible materials inaccordance with the requirements of the building code.

10 6 .4. 5.3 1 .1.1

Interior walls or partitions shall have a fire resistance rating of not less than 2 hours, shall be continuousfrom floor to ceiling, and shall be anchored to resist movement.

10 6 .4. 5.3 1 .1.2

Not less than 25 percent of the perimeter wall shall be an exterior wall.

10 6 .4. 5.3 1 .1.3

Openings to other parts of the building shall not be permitted.

10 6 .4. 5.3 1 .1.4

Windows and doors shall be in exterior walls only.

10 6 .4. 5.3 1 .2

Ventilation shall be as provided in Section 6.16.

10 6 .4. 5.3 1 .3

Explosion control shall be provided in accordance with the requirements of Section 6.9.

10 6 .4. 5.3 1 .4

There shall be no sources of ignition from open flames, electrical equipment, or heating equipment.

10 6 .4. 5.3 1 .5

Electrical equipment shall be in accordance with Article 501 of NFPA 70, for Class I, Division 2 locations.

10 6 .4. 5.3 1 .6

Heating, if provided, shall be by steam, hot water, or indirect means except that electrical heating shall bepermitted to be used if in compliance with 10.4.5.3.5.


Hydrogen gas rooms are not currently invoked in NFPA 55. They are analogous to "Hydrogen Fuel Gas Rooms" per the IFC. Hydrogen gas rooms are not useful in an indoor bulk hydrogen application which would be a high hazard PL-2 or H-2 (IFC) occupancy and subject to those requirements. A hydrogen gas room is useful in occupancies where greater than 250 cu ft of gas is needed that are not already storage or industrial occupancies. It allows the use of reasonable quantities of flammable gas with appropriate protective measures. So this change makes that possible by moving the section out of 10.4.5 (Indoor Bulk) where it only applies greater that 5000 cu ft but has no driver to invoke it, and moving it to section 6.5 following 6.4 Gas Rooms.

The current sections 6.5 and below would need to be renumbered.



Public Input No. 73-NFPA 55-2016 [New Section after 6.3.1.6.2]



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11.1.1

The storage, use, and handling of bulk liquefied hydrogen in liquefied hydrogen storage systems shall be inaccordance with the provisions of Chapters 1 through 11 as applicable and with ANSI/CGA H-5, Standardfor Bulk Hydrogen Supply Systems .


CGA H-5 provides more details for bulk hydrogen supply systems.



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The minimum distance from bulk liquefied hydrogen systems of indicated capacity shall be in accordancewith Table 11.3.2.2.

11.3.2.2.1 The distance shall be measured from the part of the bulk liquefied hydrogen system closest tothe exposure.

Table 11.3.2.2 Minimum Distance from Bulk Liquefied Hydrogen Systems to Exposures

Total Bulk Liquefied Hydrogen Storage

39.7 galto

3500 gal

150 L to13,250 L

3501 gal to15,000 gal

13,251 Lto

56,781 L

15,001 galto

75,000 gal

56,782 L to283,906 L

Type of Exposure ft m ft m ft m

Group 1

1. Lot lines 25 7.6 50 15 75 23

2. Air intakes [heating,ventilating, orair-conditioning equipment(HVAC), compressors, other]

75 23 75 23 75 23

3. Wall openings

Operable openings inbuildings and structures

75 23 75 23 75 23

4. Ignition sources such asopen flames and welding

50 15 50 15 50 15

Group 2

5. Places of public assembly 75 23 75 23 75 23

6. Parked cars (distanceshall be measured from thecontainer fill connection)

25 7.6 25 7.6 25 7.6

Group 3

7. Building or structure

(a) Buildings constructedof noncombustible or limited-combustible materials

(1) Sprinklered buildingor structure or unsprinkleredbuilding or structure havingnoncombustible contents

5a 1.5 5a 1.5 5a 1.5

(2) Unsprinkleredbuilding or structure withcombustible contents

(i) Adjacent wall(s)with fire resistance ratingless than 3 hours

25 7.6 50 15 75 23

(ii) Adjacent wall(s)with fire resistance rating of

3 hours or greaterb5 1.5 5 1.5 5 1.5

(b) Buildings ofcombustible construction

(1) Sprinklered buildingor structure

50 15 50 15 50 15

(2) Unsprinkleredbuilding or structure

50 15 75 23 100 30.5


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Total Bulk Liquefied Hydrogen Storage

39.7 galto

3500 gal

150 L to13,250 L

3501 gal to15,000 gal

13,251 Lto

56,781 L

15,001 galto

75,000 gal

56,782 L to283,906 L

Type of Exposure ft m ft m ft m

8. Flammable gas storage orsystems (other thanhydrogen) above or belowground

50 15 75 23 75 23

9. Between stationaryliquefied hydrogencontainers

5 1.5 5 1.5 5 1.5

10. All classes of flammableand combustible liquids(above ground and vent orfill openings if below

ground)c

50 15 75 23 100 30.5

11. Hazardous materialsstorage or systems includingliquid oxygen storage andother oxidizers, above orbelow ground

75 23 75 23 75 23

12. Heavy timber, coal, orother slow-burningcombustible solids

50 15 75 23 100 30.5

13. Wall openings

Unopenable openings inbuildings and structures

25 7.6 50 15 50 15

14. Inlet to undergroundsewers

5 1.5 5 1.5 5 1.5

15. Utilities overhead,including electric power,building services, orhazardous materials pipingsystems

(a) Horizontal distancefrom the vertical plane belowthe nearest overhead wire ofan electric trolley, train, orbus line

50 15 50 15 50 15

(b) Horizontal distancefrom the vertical plane belowthe nearest overheadelectrical wire

25 7.5 25 7.5 25 7.5

(c) Piping containing otherhazardous materials

15 4.6 15 4.6 15 4.6

16. Flammable gas meteringand regulating stationsabove grade

15 4.6 15 4.6 15 4.6

a Portions of wall less than 10 ft (3.1 m) (measured horizontally) from any part of a system must have a fireresistance rating of not less than 1 hour.

b Exclusive of windows and doors.

c The separation distances for Class IIIB combustible liquids shall be permitted to be reduced to 15 ft


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(4.6 m).


The NFPA 2 / 55 hydrogen separations task group found a gap in the code where there is no specific guidance on measuring exposure distances.



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11.3.2.2.2*

The distances in 1, 7, 8, 10, 11, and 12 in Table 11.3.2.2 shall be permitted to be reduced to 5 ft (1.5 m) bythe use of fire barrier walls having a fire resistance rating of not less than 2 hours when constructed inaccordance with 8.7.2.1 and 11.3.2.2.


Section 11.3.2.2.2 states that separation distances can be reduced by the use of fire barrier walls but does not specify the amount of reduction. The separation distances table in NFPA 50B, which covered liquid hydrogen systems and has been incorporated into NFPA 55, called out a 5 ft distance to fire barrier walls (also called protective structures) as shown in the 1994 edition.



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11.3.2.3

Unloading connections on delivery equipment shall not be positioned closer to any of the exposures cited inTable 11.3.2.2 than the distances given for the storage system.

11.3.2.3.1

The distance to unloading connection to exposures shown in table 11.3.3.3(A) Group 1 and Group 2 maybe reduced to 50 feet when the following active mitigation methods are installed and employed as standardpractice at the bulk liquid hydrogen storage site:

(a) the installed bulk liquid hydrogen system shall include equipment to allow for connection of both liquidtransfer (fill) hose and a separate trailer “head space” vent hose to connect to the bulk storage system ventstack.

(b) all liquid hydrogen delivery trailers shall utilize a vent hose connection method to vent the trailer headspace to the bulk storage vent stack system at the end of the bulk liquid hydrogen trans-fill process.

(c) the liquid hydrogen delivery procedures shall incorporate the physical changes required in (a) and (b)above to eliminate “end of trans-fill venting” at the trailer vent stack.

(d) all liquid hydrogen delivery trailers trans-filling at the site are equipped with an emergency shutdown(ESD) system and fast acting liquid hydrogen shut off valve that will isolate the trailer in the event of anemergency during the trans-fill process


The existing setback distance required by NFPA section are based on the vent-down of trailer headspace after fueling events happening at the back of the trailer, where there is a relatively low-to-the-ground vent stack on the top of the trailer. By moving the discharge point of the trans-fill related vent release from the back end of the trailer vent to the much taller bulk storage system vent the key drivers for the separation distance from the back of the trailer has been eliminated.

These alternative trans-fill procedures reduce the setback distance requirements from the back of the trailer, and minimize the risks associated with the liquid hydrogen trans-fill process. Based on the supporting information at the time of this submittal, the setback distance from the end of the trailer, the fill connection point and fill connections on the liquid hydrogen trailer shall be a minimum of 50 feet. The Linde North American engineering and risk management teams have reviewed the potential for leaks and has chosen as a worst case a 10% leak area of the liquid transfer hose. Linde engineering standards are based on high pressure oilfield leak data known as the Dutch Purple Book Table and 3.19 to show a likelihood of 4x10^-5.yr for leaks of up to 10% leak area for equipment such as the 1.5" ID Vacuum Jacketed Air Force-type bayonet hose according to the guidelines of Appendix H of NFPA 55.

The need for setback distance from the fill point to be equal to the setback distance of the installed bulk liquid hydrogen tank is no longer necessary with the use of the improved trans-fill procedures which eliminates the need to vent hydrogen from the back end of the trailer at the end of the trans-fill event. The distance to exposures is now driven by the potential leaks in the liquid hydrogen transfer hose, connections and devices on the trailer and the control valves on the bulk liquid hydrogen tank and conservative modeling of those leaks show a worst case leak with a 41 foot range of flammability (based on the conservative 4% LFL and 10 % leak area assumptions). Linde has implemented PHAST dispersion models to calculate the horizontal distance to the 4% volume fraction concentration (LFL) of hydrogen in air at the 7ft (door height) elevation to be 41 feet. This is a very conservative large leak rate assumption and although the probability of such a leak is extremely low, the horizontal distance such a hydrogen jet could travers in unfavorable wind conditions (same direction as the jet) is 41 feet. NFPA 55 setback distances are currently based on 3% leak area (still very conservative) and Linde PHAST modeling using the of the NFPA 2 shows a horizontal distance of 14.5 feet to the LFL of 4%. If we are to use the


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assumptions from the NFPA-2 Task Group and the worst case leaks that will be accepted by the NFPA 2 and NFPA 55 technical committee for the 3rd edition of NFPA 2, for compressed setback distances the assumptions would be 1% leak area and effective LFL for hydrogen in air at 8% and this would justify perhaps a 25 foot setback distance from the back end of the trailer and from the liquid hydrogen fill connection point.

It is possible that Sandia, BoydH2 and Linde members of the Liquid H2 separations task group may be able to provide further justification to allow for a greater reduction of setback distance to the back end of the trailer than this proposal for changing from 75 to 50 feet .




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11.3.3 Installation of LH2 Inside Buildings Other Than Detached Buildings and Gas Rooms.

Portable liquefied hydrogen (LH2) containers of 39.7 gal (150 L) or less capacity where housed inside

buildings, not located in a gas room, and exposed to other occupancies shall comply with the followingminimum requirements:

(1) Containers shall be located 20 ft (6.1 m) from all classes of flammable or combustible liquids andcombustible materials such as excelsior or paper.

(2) Containers shall be located 25 ft (7.6 m) from ordinary electrical equipment and other sources ofignition, including process or analytical equipment. (See Section 8.7.)

(3) Containers shall be located 50 ft (15 m) from intakes for ventilation, air-conditioning equipment, orcompressors.

(4) Containers shall be located 50 ft (15 m) from storage or use of other flammable gases or storage oruse of incompatible gases.

(5) Containers shall be protected against physical damage in accordance with the requirements of 8.6.5.

(6) Containers shall be secured in accordance with the requirements of 8.6.3.

(7) Welding or cutting operations and smoking shall be prohibited while hydrogen is in the room allowedto vent into the area , and signs shall be provided as required by 6.12.2.2.

(8) Ventilation shall be provided in accordance with the requirements of Section 6.16.

(9) Pressure relief devices on stationary or portable containers shall be vented directly outdoors or to anexhaust hood. (See 8.2.4.6.)


Clarify intent. If nothing is released into the room, there is no hazard over and above a “hot work” permit. Request collaborating with NFPA 2 TC as this text is extracted into NFPA 2.




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Public Input No. 11-NFPA 55-2016 [ Chapter 13 [Title Only] ]

Insulated Liquid Carbon Dioxide Systems


The title is misleading as this chapter also refers to uninsulated Carbon Dioxide Systems.



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13.2 Uninsulated Carbon Dioxide Compressed Gas Systems.

The storage, use, and handling of carbon dioxide in uninsulated systems shall be in accordance with theprovisions of Chapter 13 and Chapters 1 through 7 as applicable .


Inclusion of as applicable, matches the verbiage used in 2013 NFPA 55 13.1 General. The storage, use, and handling of liquid carbon dioxide in insulated systems shall be in accordance with the provisions of Chapter 13 and Chapters 1 through 7 as applicable.



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13.3.1 Insulated Carbon Dioxide Compressed Gas Systems

The storage, use, and handling of carbon dioxide in insulated systems shall be in accordance with theprovisions of Chapter 13 and Chapters 1 through 7 as applicable.


Adding this section defines what an Insulated Liquid Carbon Dioxide Compressed Gas System must be compliant with.



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Carbon dioxide storage tanks, cylinders, piping, and equipment located indoors, in rooms, and other areaswhere a leak of carbon dioxide can collect shall be provided with either ventilation in accordance with13.10.4.1 or an emergency alarm system in accordance with 13.10.4.2.


This appears to be a scrivener's error. This change was originally intended to harmonize with 2015 IFC 5307.5 Required Protection, and by adding the word “OR” will correct the error. The absence of the word OR creates confusion for the Authority Having Jurisdiction.



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Public Input No. 35-NFPA 55-2016 [ Section No. A.1.1.2(3) ]

A.1.1.2(3)

Bulk compressed gas and cryogenic fluid Cryogenic fluid central supply system installations are intendedto be covered by the requirements of this code. Instrumentation and alarms that are attendant to the systemand designed to interface with the application in a health care facility are to be retained within the purviewof NFPA 99. See Section 17.1.2.


The NFPA 99/55 Task Group is proposing a new chapter for Cryogenic Fluid Central Supply Systems for Health Care Facilities. This change is to correct the "name" of the supply system so it is constant in the document and with NFPA 99. Also added the section to reference for the reader.



Public Input No. 34-NFPA 55-2016 [Section No. 1.1.2]




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Public Input No. 44-NFPA 55-2016 [ Section No. A.3.3.40 ]

A.3.3.40 Exhausted Enclosure.

Such enclosures include laboratory hoods, exhaust fume hoods, and similar appliances and equipmentused to retain and exhaust locally the gases, fumes, vapors, and mists that could be released. Rooms orareas provided with general ventilation including rooms , such as control areas, with dedicated hazardousvapor/gas exhaust systems, in and of themselves, are not exhausted enclosures.


There is confusion in the industry as to what constitutes an exhausted enclosure. The definition clearly states that the exhausted enclosure has to be an appliance or equipment for local capture. However, based on the existing annex material some people interpret that only rooms with general building HVAC cannot be classified as an exhausted enclosures and as soon as you add a dedicated exhaust system to the room it becomes an exhausted enclosure. This does not seem to match the intent of the definition. The added text will limit the interpretation for an entire room becoming the exhausted enclosure when it has a dedicated exhaust system.

If it is the intent of the committee to allow entire rooms to be considered exhausted enclosures when provided with a dedicated exhaust system then the definition in Chapter 3 must be revised to include these rooms.


Submitter Full Name: Kurt Ruchala

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Public Input No. 27-NFPA 55-2016 [ New Section after A.5.1.1 ]

A.6.3.1.1 Where an exhausted enclosure (such as a gas cabinet, gas room, etc.) is used to increasethe MAQ and gas cylinders are also stored outside of the exhausted enclosures, the maximumallowable quantity may be normalized as follows:



Hazardous_material_stored_inside_outside_of_required_enclosure.pdf

Equation for determining MAQ quantities for materials inside and outside of cabinets


The code does not address how to manage MAQ when gas bottles are stored both inside of and outside of gas cabinets (for example, a situation where a gas bottle is only needed temporarily that doesn't warrant an installation of a cabinet).




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Public Input No. 15-NFPA 55-2016 [ Section No. A.6.5 ]

A.6.5

Bulk hydrogen compressed gas systems terminate at the source valve. In cylinder filling or packagingoperations, cylinders located on filling manifolds located downstream of the source valve are notconsidered to be part of the bulk gas system. For definitions of source valve and bulk hydrogencompressed gas system, see 3.3.89 and 3.3.94.9.1. Additional requirements for source valves can befound in Section 6.19. This 15,000 scf threshold only applies to the supply and not to cylinders being filledfrom the system. An example of individual bulk hydrogen system would be supply containers manifoldedtogether into an individual system, such as a bundle or a tube trailer that exceeds 15,000 scf that isintended to feed a process.


To make it clear that it is the supply system that includes cylinders manifolded together into an individual system or even a single large container that feeds a process and exceeds 15,000 SCF. It doesn't include the cylinders being filled. This is the original intent that was intended to be preserved when this information was transferred from NFPA 50A.



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Public Input No. 16-NFPA 55-2016 [ New Section after A.8.13.2.7.2 ]

A.8.13.2.7.1

CGA P-41, Locating Bulk Storage Systems in Courts, provides methodology to determine the suitability of acourt or enclosed court.


CGA developed P-41 to provide methods to assess courts and enclosed courts. Having the document referenced in NFPA 55 will help it to be used more often.



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Public Input No. 18-NFPA 55-2016 [ New Section after A.9.3.2.1 ]

A.Table 9.3.2(18)

Table 9.3.2, line (12) defines the exposure distances to flammable gas storage systems as a function oftype and quantity of stored flammable gases. Line (18) defines the exposure distance to flammable gas in apiping system that may not be associated with a storage system. An example is a flammable gas pipeline. The pipeline may be aboveground, belowground, or transition to above and below ground. The exposuredistance applies to the parts of the flammable gas piping system, including the piping and in-linecomponents, that are located aboveground. The exposure distance does not apply to the undergroundportion of the pipeline.


The annex note is meant to clarify the use of the exposure distance and to explain underground flammable gas piping from the section removed in the note above.



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A.10.4.2.2.1

Clarification of types of exposures and application of the distances should be in accordance with CGAPS-48, Clarification of Existing Hydrogen Setback Distances and Development of New Hydrogen SetbackDistances in NFPA 55.


CGA PS-48 was developed to clarify the gas and liquid hydrogen setback distances and to deal with code gaps.



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Public Input No. 26-NFPA 55-2016 [ New Section after A.11.3.2.2 ]

A.11.3.2.2.1

Clarification of types of exposures and application of the distances should be in accordance with CGAPS-48, Clarification of Existing Hydrogen Setback Distances and Development of New Hydrogen SetbackDistances in NFPA 55.


CGA PS-48 was developed to clarify the gas and liquid hydrogen setback distances and to deal with code gaps.



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Pressure and Level Indicators

Where cylinders, containers, and tanks are in locations remote from the filling connection, a means todetermine when the containers have been filled to their design capacity shall be provided and shall beverifiable from the filling connection. A functional pressure gauge equipped on the filling equipmentconnected to the fill box on the outside of the building is one method used to determine when the containerbeing filled and the delivery vehicle pressures quickly equalize and the transfer of product is complete.


Authority Having Jurisdiction are confused believing that a contents gauge is required in the fill box to determine when the container has been filled to its design capacity. Furthermore, this change will harmonize with 2013 CGA G-6.5, Standard for Small Stationary Insulated Carbon Dioxide Supply Systems.



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Public Input No. 4-NFPA 55-2015 [ Chapter I ]

Annex I Informational References

I.1 Referenced Publications.

The documents or portions thereof listed in this annex are referenced within the informational sections ofthis code and are not part of the requirements of this document unless also listed in Chapter 2 for otherreasons.

I.1.1 NFPA Publications.



NFPA 2, Hydrogen Technologies Code, 2016 edition.


NFPA 50A, Standard for Gaseous Hydrogen Systems at Consumer Sites, 1969 edition.

NFPA 51, Standard for the Design and Installation of Oxygen–Fuel Gas Systems for Welding, Cutting, andAllied Processes, 2013 edition.

NFPA 51B, Standard for Fire Prevention During Welding, Cutting, and Other Hot Work, 2014 edition.


NFPA 53, Recommended Practice on Materials, Equipment, and Systems Used in Oxygen-EnrichedAtmospheres, 2011 edition.






NFPA 77, Recommended Practice on Static Electricity, 2014 edition.


NFPA 101 ©, Life Safety Code, 2015 edition.




NFPA 497, Recommended Practice for the Classification of Flammable Liquids, Gases, or Vapors and ofHazardous (Classified) Locations for Electrical Installations in Chemical Process Areas, 2012 edition.

NFPA 505, Fire Safety Standard for Powered Industrial Trucks Including Type Designations, Areas of Use,Conversions, Maintenance, and Operations, 2013 edition.

NFPA 704, Standard System for the Identification of the Hazards of Materials for Emergency Response,2012 edition.


I.1.2 Other Publications.


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I.1.2.1 ACGIH Publications.

American Conference of Governmental Industrial Hygienists, 1330 Kemper Meadow Drive, Cincinnati, OH45240.

TLVs ® and BEIs ®, Threshold Limit Values for Chemical Substances and Physical Agents and BiologicalExposure Indices, 2013 2016 edition.

I.1.2.2 API Publications.

American Petroleum Institute, 1220 L Street, NW, Washington, DC 20005-4070.

API RP 579-1/ASME FFS-1 Fitness for Service , Second Edition, June 2007, Errata, 2009 .

I.1.2.3 ASME Publications.

American Society of Mechanical Engineers ASME International , Two Park Avenue, New York, NY10016-5990.


Boiler and Pressure Vessel Code, “Rules for the Construction of Unfired Pressure Vessels,” Section VIII,2013 2015 .


I.1.2.4 ASTM Publications.


ASTM A380/A380 M A380M , Standard Practice for Cleaning, Descaling, and Passivation of Stainless SteelParts, Equipment, and Systems, 2013.

ASTM E681, Standard Test Method for Concentration Limits of Flammability of Chemicals (Vapors andGases), 2009, reapproved 2015 .

I.1.2.5 BSI Publications.

BSI British Standards, 389 Chiswick High Road, London, W4 4AL, England.

BS 7910, Guide to Methods for Assessing the Acceptability of Flaws in Metallic Structures , 2013 ,Corrigendum, 2015.

I.1.2.6 CGA Publications.


CGA G-1.6, Standard for Mobile Acetylene Trailer Systems, 2011.

CGA G-1.7, Standard for Storage and Handling of Calcium Carbide in Containers, 2012.

CGA G-8.1, Standard for Nitrous Oxide Systems at Consumer Sites, 2013.

CGA H-3, Cryogenic Hydrogen Storage, 2013.

ANSI/ CGA H-5, Installation Standards for Bulk Hydrogen Supply Systems, 2008 2014 .

ANSI/CGA P-18, Standard for Bulk Inert Gas Systems at Consumer Sites, 2013.

CGA P-52, Security Standard for Qualifying Customers Purchasing Compressed Gases, 2007 2014

CGA SB-4, Handling Acetylene Cylinders in Fires, 2012.

CGA SB-6, Nitrous Oxide Security Standard, 2014.

CGA S-1.3, Pressure Relief Device Standards – Part 3 – Stationary Storage Containers for CompressedGases, 2008.

I.1.2.7 ICC Publications.

500 New Jersey Avenue, NW, 6th Floor, Washington, DC 20001-2070.

International Fuel Gas Code (IFCG), 2012 2015 .


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I.1.2.8 UL Publications.

Underwriters Laboratories, 333 Pfingsten Road, Northbrook, IL 60062-2096.

ANSI/UL 558, Standard for Safety Industrial Trucks, Internal Combustion Engine–Powered, 1996, Revised2012 2012 , r evised 2015 .

ANSI/UL 583, Standard for Safety Electric-Battery-Powered Industrial Trucks, 1996, Revised 2012 2012 ,r evised 2015 .

ANSI/UL 2075, Standard for Gas and Vapor Detectors and Sensors, 2013.

I.1.2.9 U.S. Government Publications.

U.S. Government Publishing Office, 732 North Capitol Street, NW, Washington, DC 20402 20401-0001 .

Title 29, Code of Federal Regulations, Part 1910.38, “Emergency Action Plans.”

Title 29, Code of Federal Regulations, 1910.103, “Hydrogen.”

Title 29, Code of Federal Regulations, Part 1910.119, “Process Safety Management of Highly HazardousMaterials.”

Title 29, Code of Federal Regulations, Part 1910.165, “Employee Alarm Systems.”

Title 29, Code of Federal Regulations, Part 1910.1000, “Air Contaminants.”

Title 29, Code of Federal Regulations, Part 1910.1047, “Ethylene Oxide.”

Title 29, Code of Federal Regulations, Part 191.1200, “Hazard Communication.”

Title 40, Code of Federal Regulations, Part 68, “Chemical Accident Prevention Provisions.”

Title 49, Code of Federal Regulations, Parts 100–179, “Hazardous Materials Regulations.”

Title 49, Code of Federal Regulations, Parts 100–185, “Transportation.”

I.2 Informational References.

The following documents or portions thereof are listed here as informational resources only. They are not apart of the requirements of this document.

I.2.1 NFPA Publications.


NFPA 51, Gas Systems for Welding, Cutting, 1969 edition.

NFPA 86, Ovens and Furnaces, 2011 edition.


NFPA 566, Bulk Oxygen Systems at Consumer Sites, 1969 edition.

NFPA 850, Recommended Practice for Fire Protection for Electric Generating Plants and High VoltageDirect Current Converter Stations, 2015 edition.

I.2.2 CGA Publications.

Compressed Gas Association, 1405 George Carter Way, Suite 103, , Chantilly, VA 20151-2923 1788 .

CGA G-5.5, Hydrogen Vent Systems, 2004, reaffirmed 2014.



CGA G-6.7, Safe Handling of Liquid Carbon Dioxide Containers That Have Lost Pressure, 2009.

CGA H-1, Service Conditions for Portable, Reversible Hydride Systems, 2011.

CGA H-2, Guidelines for the Classification and Labeling of Hydrogen Storage Systems with HydrogenAbsorbed in Reversible Metal Hydrides, 2004 reaffirmed 2010.

ANSI/ CGA H-5, Installation Standards for Bulk Hydrogen Supply Systems, 2008 2014 .


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I.2.3 Other Publications.

ANSI/AIAAGuide AIAA G- 095, Guide to Safety of Hydrogen and Hydrogen Systems, 2004.

Floyd, J., “Siting Requirements for Hydrogen Supplies Serving Fuel Cells in Non-Combustible Enclosures,”Hughes Associates, Inc., 3610 Commerce Drive, Suite 817, Baltimore, MD 21227, HAI Project #3250-000,November 30, 2006. Fire Protection Research Foundation, 2006.

Houf, W., and R. Schefer, “Analytical and Experimental Investigation of Small-Scale Unintended Releasesof Hydrogen,” Inter. J. Hydrogen Energy 33:1435–1444, 2008.

Houf, W., and R. Schefer, “Predicting Radiative Heat Fluxes and Flammability Envelopes from UnintendedReleases of Hydrogen,” Inter. J. Hydrogen Energy, 32:136–151, 2007.

W. Houf, R. Schefer, G. Evans, E. Merilo, and M. Groethe, “Evaluation of Barrier Walls for Mitigation ofUnintended Releases of Hydrogen,” International Journal of Hydrogen Energy, Vol. 35, Issue 10, May 2010,pp. 4758-4775.

LaChance, J., W. Houf, B. Middleton (all of Sandia National Laboratories), and L. Fluer (of Fluer, Inc.),“Analyses to Support Development of Risk-Informed Separation Distances for NFPA Hydrogen Codes andStandards,” SAND 2009-0874, Sandia National Laboratories, Albuquerque, NM 87185, and Livermore, CA94550, March 2009.

LaChance, J., W. Houf, R. Schefer, and G. Evans, “Analysis of Barriers for Mitigation of UnintendedReleases of Hydrogen.” Paper presented at Annual Hydrogen Conference and Hydrogen Expo USA, March30–April 3, 2008, Sacramento, CA.

LaChance, J., Phillips, J., Houf, W., “Risk Associated with the Use of Barriers in Hydrogen RefuelingStations,” National Hydrogen Association Conference & Expo, Long Beach, California, May 3–6, 2010.

“NIOSH Alert: Preventing Worker Injuries and Deaths from Explosions in Industrial Ethylene OxideSterilization Facilities.” Available at www.cdc.gov/niosh/homepage.html.

Schefer, R., W. Houf, B. Bourne, and J. Colton, “Spatial and Radiative Properties of an Open-FlameHydrogen Plume,” Inter. J. Hydrogen Energy 31:1332–1340, 2006.

Schefer, R., W. Houf, T. C. Williams, B. Bourne, and J. Colton, “Characterization of High-Pressure,Underexpanded Hydrogen-Jet Flames,” Inter. J. Hydrogen Energy 32:2081–2093, 2007.


API Spec 5L, Specification for Line Pipe, 44th edition, 2012, Errata, 2015 .

ASME B36.10M, Welded and Seamless Wrought Steel Pipe, 2004 2015 .

Title 29, Code of Federal Regulations, 191.1200, “Hazard Communication.”

Title 49, Code of Federal Regulations, Parts 100–179, “Hazardous Materials Regulations.”

I.3 References for Extracts in Informational Sections.








Referenced current SDO names, addresses, standard names, numbers, and editions.Please update NFPA documents editions in I2.1.




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Public Input No. 3-NFPA 55-2015[Chapter 2]

Referenced current SDO names, addresses, standard names,numbers, and editions.




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Submittal Date: Mon Dec 21 15:46:08 EST 2015


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Public Input No. 52-NFPA 55-2016 [ Section No. I.1.2.8 ]

I.1.2.8 UL Publications.

Underwriters Laboratories, 333 Pfingsten Road, Northbrook, IL 60062-2096.

ANSI/UL 558, Standard for Safety Industrial Trucks, Internal Combustion Engine–Powered, 1996, Revised2012 2015 .

ANSI/UL 583, Standard for Safety Electric-Battery-Powered Industrial Trucks, 1996, Revised 2012 2016 .

ANSI/UL 2075, Standard for Gas and Vapor Detectors and Sensors, 2013.


This proposal updates the referenced UL Standards to the current edition.




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