second revision no. 15-nfpa 59-2016 [ global comment...

Second Revision No. 15-NFPA 59-2016 [ Global Comment ]

Chapter 7

Piping, Valves, Process Pressure Vessels and Equipment

Submitter Information Verification

Submitter Full Name: Eric Nette

Organization: [ Not Specified ]

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Submittal Date: Wed Aug 31 13:34:14 EDT 2016

Committee Statement

CommitteeStatement:

The additional recognition of process pressure vessels that may be used and are notstorage containers by definition.

ResponseMessage:

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

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Second Revision No. 24-NFPA 59-2016 [ Global Comment ]

Substitute the term "Fire Protection" for all instances of "Fire Control".




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Committee Statement

CommitteeStatement:

The term "Fire Protection" is sufficient to cover the instances where the specific definition"Fire Control" is used.

ResponseMessage:


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Second Revision No. 26-NFPA 59-2016 [ Section No. 1.2 ]

1.2 Purpose. (Reserved)

The purpose of this standard is to provide minimum fire protection, safety, and related requirements forthe location, design, construction, security, operation, and maintenance of utility LP-Gas plants.




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Committee Statement

Committee Statement: The stated purpose adds clarity to the code.

Response Message:


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2.2 NFPA Publications.

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

NFPA 10, Standard for Portable Fire Extinguishers, 2017 edition.

NFPA 11, Standard for Low-, Medium-, and High-Expansion Foam, 2016 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, 2016 edition.

NFPA 15, Standard for Water Spray Fixed Systems for Fire Protection, 2017 edition.

NFPA 16, Standard for the Installation of Foam-Water Sprinkler and Foam-Water Spray Systems, 2015edition.

NFPA 17, Standard for Dry Chemical Extinguishing Systems, 2017 edition.

NFPA 20, Standard for the Installation of Stationary Pumps for Fire Protection, 2016 edition.

NFPA 22, Standard for Water Tanks for Private Fire Protection, 2013 edition.

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

NFPA 25, Standard for the Inspection, Testing, and Maintenance of Water-Based Fire Protection Systems,2017 edition.

NFPA 30, Flammable and Combustible Liquids Code, 2015 2018 edition.

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

NFPA 54, National Fuel Gas Code, 2015 2018 edition.

NFPA 58, Liquefied Petroleum Gas Code, 2014 2017 edition.

NFPA 70®, National Electrical Code®, 2017 edition.

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

NFPA 101®, Life Safety Code®, 2015 2018 edition.

NFPA 290, Standard for Fire Testing of Passive Protection Materials for Use on LP-Gas Containers, 2013edition.

NFPA 780, Standard for the Installation of Lightning Protection Systems, 2017 edition.

NFPA 1961, Standard on Fire Hose, 2013 2018 edition.

NFPA 1962, Standard for the Care, Use, Inspection, Service Testing, and Replacement of Fire Hose,Couplings, Nozzles, and Fire Hose Appliances, 2013 edition.

NFPA 1963, Standard for Fire Hose Connections, 2014 edition.

NFPA 1971, Standard on Protective Ensembles for Structural Fire Fighting and Proximity Fire Fighting,2013 2018 edition.

NFPA 1981, Standard on Open-Circuit Self-Contained Breathing Apparatus (SCBA) for EmergencyServices, 2013 edition.

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



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Organization: National Fire Protection Assoc

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Submittal Date: Mon Oct 10 08:44:42 EDT 2016

Committee Statement

CommitteeStatement:

NFPA 16 is not referenced in the body of the Code and therefore cannot be referenced inChapter 2.

Response Message:


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2.4 References for Extracts in Mandatory Sections.

NFPA 54, National Fuel Gas Code, 2015 2018 edition.

NFPA 58, Liquefied Petroleum Gas Code, 2017 edition.

NFPA 5000®, Building Construction and Safety Code®, 2015 2018 edition.




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Committee Statement

Committee Statement: Edition years for NFPA documents have been updated.

Response Message:


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Second Revision No. 1-NFPA 59-2016 [ New Section after 3.3.3 ]

3.3.9* Component.

A uniquely identifiable part, piece, assembly, or subassembly that performs a distinctive and necessaryfunction in the operation of a LP-Gas facility or system.




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Submittal Date: Tue Aug 30 14:37:24 EDT 2016

Committee Statement

CommitteeStatement:

A similar approach using these terms were added in the latest edition of the NFPA 59A LNGstandard. This will add clarity to these commonly used terms and ensure that the AHJ has a clearunderstanding of the requirements for the utility gas plants. Where an AHJ that enforces safetycodes at both LP-Gas Utility Plant and LNG Facilities, the use of the same terms should aid inconsistent enforcement.

ResponseMessage:

Public Comment No. 6-NFPA 59-2016 [New Section after 3.3.3]


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3.3.13 Facility.

A number of components installed and designed to function as an independent process as part of anLP-Gas plant.




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3.3.28 Plant.

The entirety of facilities, buildings, and related structures co-located on a single or adjacent property.




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Committee Statement

CommitteeStatement:

A similar approach using these terms were added in the latest edition of the NFPA 59A LNGstandard.This will add clarity to these commonly used terms and ensure that the AHJ has a clearunderstanding of the requirements for the utility gas plants. Where an AHJ that enforces safetycodes at both LP-Gas Utility Plant and LNG Facilities, the use of the same terms should aid inconsistent enforcement.

ResponseMessage:



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3.3.32 Process Pressure Vessel.

A vessel, other than that used as an LP-Gas container (as defined in 3.3.10 ) , operating at pressuresexceeding 15 psig (103 kPa) that is used as, but is not limited to, part of the LP-Gas loading/unloadingprocess or for separation, filtering, and mixing/blending in the LP-Gas/LP-Gas–air supply process.




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Committee Statement

CommitteeStatement:

The new definition supports revised text from Second Revision 14 and Second Revision15.

Response Message:


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Second Revision No. 11-NFPA 59-2016 [ Section No. 4.5.2.2 ]


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4.5.2.2*


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Fixed electrical equipment and wiring installed within the classified areas specified in Table 4.5.2.2 shallcomply with Table 4.5.2.2 and shall be installed in accordance with NFPA 70.

Table 4.5.2.2 Electrical Area Classification

Part Location Extent of Classified Areaa

Equipment Shall BeApproved for National

Electrical Code,

Class Ia, Group Db

A

Unrefrigerated containers otherthan cylinders and ASMEvertical containers of less than1000 lb (454 kg) watercapacity

Within 15 ft (4.6 m) in all directions fromconnections, except connectionsotherwise covered in Table 4.5.2.2

Division 2

B

Refrigerated storagecontainers

Within 15 ft (4.6 m) in all directions fromconnections otherwise covered in Table4.5.2.2

Division 2

Area inside dike to the level of the top ofthe dike

Division 2

Cc

Tank vehicle and tank carloading and unloading

Within 5 ft (1.5 m) in all directions fromconnections regularly made ordisconnected for product transfer

Division 1

Beyond 5 ft (1.5 m) but within 15 ft (4.6 m)in all directions from a point whereconnections are regularly made ordisconnected and within the cylindricalvolume between the horizontal equator ofthe sphere and grade (see FigureA.4.5.2.2)

Division 2

D

Gauge vent openings otherthan those on cylinders andASME vertical containers ofless than 1000 lb (454 kg)water capacity

Within 5 ft (1.5 m) in all directions frompoint of discharge

Division 1

Beyond 5 ft (1.5 m) but within 15 ft (4.6 m)in all directions from point of discharge

Division 2

E

Relief device discharge otherthan those on cylinders andASME vertical containers ofless than 1000 lb (454 kg)water capacity and vaporizers

Within direct path of discharge

Note: Fixed electricalequipment shouldpreferably not be

installed. Division 1


Division 1

Beyond 5 ft (1.5 m) but within 15 ft (4.6 m)in all directions from point of discharge,except within path of discharge

Division 2

Fc

Pumps, vapor compressors,gas–air mixers and vaporizers(other than direct-fired orindirect-fired with an attachedor adjacent gas-fired heatsource)

Indoors without ventilationEntire room and any adjacent room notseparated by a gastight partition

Division 1

Within 15 ft (4.6 m) of the exterior side ofany exterior wall or roof that is notvaportight or within 15 ft (4.6 m) of anyexterior opening

Division 2


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Part Location Extent of Classified Areaa

Equipment Shall BeApproved for National

Electrical Code,

Class Ia, Group Db

Indoors with ventilationEntire room and any adjacent room notseparated by a gastight partition

Division 2

Outdoors in open air at orabove grade

Within 15 ft (4.6 m) in all directions fromthis equipment and within the cylindricalvolume between the horizontal equator ofthe sphere and grade (see FigureA.4.5.2.2)

Division 2

G

Pits or trenches containing orlocated beneath LP-Gasvalves, pumps, vaporcompressors, regulators, andsimilar equipment

Without mechanical ventilation Entire pit or trench Division 1

Entire room and any adjacent room notseparated by a gastight partition

Division 2

Within 15 ft (4.6 m) in all directions from pitor trench when located outdoors

Division 2

With mechanical ventilation Entire pit or trench Division 2

Entire room and any adjacent room notseparated by a gastight partition

Division 2

Within 15 ft (4.6 m) in all directions from pitor trench when located outdoors

Division 2

H

Pipelines and connectionscontaining operational bleeds,drips, vents, or drains


Division 1

Beyond 5 ft (1.5 m) from point ofdischarge, same as part F of this table

I Piers and wharvesWithin 5 ft (1.5 m) in all directions fromconnections regularly made ordisconnected for product transfer

Division 1

Beyond 5 ft (1.5 m) but within 15 ft (4.6 m)in all directions from a point whereconnections are regularly made ordisconnected and within the cylindricalvolume between the horizontal equator ofthe sphere and the vessel deck (seeFigure A.4.5.2.2)

Division 2

aThe classified area shall not extend beyond an unpierced wall, roof, or solid vaportight partition.

bSee Article 500 Hazardous (Classified) Locations, in NFPA 70 for definitions of classes, groups, anddivisions.

cSee A.4.5.2.2.

Supplemental Information

File Name Description

SR-11_Table_4.5.2.2_reference.png Displaying Row E. For staff use



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Committee Statement

CommitteeStatement:

The committee would like to return Row E to how it appeared in the 1998 version of the code.The hazard exists in this area and requires the proper application of hazardous classified areas.

ResponseMessage:

Public Comment No. 15-NFPA 59-2016 [Section No. 4.5.2.2]


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Second Revision No. 9-NFPA 59-2016 [ Section No. 4.7.2 [Excluding any Sub-Sections]

]

Each new and modified plant facility shall retain records of materials of construction for process equipmentpiping systems containing LP-Gas and other flammable fluids, including their supporting system andfoundations.




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12.3.1.1

Cathodic protection of buried or submerged components shall comply with the following:

(1) Tests are required after Components meeting the requirements of 4.10.3.1 shall be tested 6 monthsof burial of the system identified in 4.10.1 including after initial burial . Tests shall include , includingtests for component-to-soil potential measurements with respect to either a continuous reference cellelectrode or an electrode using close spacing, not to exceed 20 ft (6 m), and soil resistivitymeasurements at potential profile peak locations to evaluate the potential profile at the component oralong the pipeline. If tests indicate that a corrosive condition exists, the affected components shall becathodically protected in accordance with Section 4.1012.3 .

(2) After the initial testsin required by 12.3.1.1(1) , additional tests shall be conducted every 3 years andnot exceeding 39 months to reevaluate the condition of the unprotected components. If tests indicatethat an active corrosion exists by either by electrical survey of leak repair or exposed pipe inspectionrecords, the affected components shall be cathodically protected in accordance with Section 4.10.

(3) Cathodic protection systems installed in accordance with 4.10 shall be monitored by testing and theresults documented and retained per 12.10.2(3).

(4)

(5) Each buried or submerged component under cathodic protection shall be tested by personnelqualified to perform corrosion control monitoring at least once each calendar year, with intervals notexceeding 15 months, to determine whether the cathodic protection is performing as designed.

(6) Each cathodic protection rectifier or other impressed current power source shall be inspected bypersonnel qualified to perform corrosion control monitoring at least six times each calendar year, withintervals not exceeding 21⁄2 months, to ensure that it is performing as designed.

(7) Each reverse current switch, each diode, and each interference bond whose failure would jeopardizecomponent protection shall be electrically checked for proper performance at least six times eachcalendar year, with intervals not exceeding 21⁄2 months, by personnel qualified to perform corrosioncontrol monitoring. Each other interference bond shall be checked at least once each calendar year,with intervals not exceeding 15 months.

(8) Whenever any portion of a buried pipe is exposed, the exposed portion of the pipe shall be examinedfor evidence of external corrosion in either of the following instances:

(a) If general external or localized external pitting corrosion is identified, additional examination inthe exposed area is necessary to identify the extent of the corrosion.

(b) If damage to the component coating is observed, the coating shall be repaired in accordancewith 4.10.1.1.2.




Street Address:

* Cathodic protection system tests shall be described by one of the following:

(a) Producing a voltage of −0.85 volts or more negative, with reference to a saturated copper–copper sulfate half cell

(b) Producing a voltage of −0.78 volts or more negative, with reference to saturated KCl calomel halfcell

(c) Producing a voltage of −0.80 volts or more negative, with reference to a silver–silver chloride halfcell


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Committee Statement

CommitteeStatement:

Existing section 4.10.3.2: This section is part of text moved from Chapter 12 to Chapter 4 in thefirst draft meeting. It refers to testing which is to take place well after initial installation so shouldmore properly be located in the maintenance section to reduce the chance it will be missed.

Move section 4.10.3.2 (numbered as 12.3.3.3.2 in 2015 edition) to Chapter 12 as a new12.3.1.1(1) and re-number the remaining sections. Correct references.

Change wording slightly to: Components meeting the requirements of 4.10.3.1 shall be tested 6months after initial burial. Tests shall include component-to-soil potential ... in accordance withsection 4.10.

Existing section 4.10.3.3: This section is part of text moved from Chapter 12 to Chapter 4 in thefirst draft meeting. It refers to testing for components without cathodic protection installed. Sincethis testing will be done on a regular basis, it should be located in the maintenance section.

Move section 4.10.3.3 (numbered as 12.3.3.3.3 in 2015 edition) to Chapter 12 as a new12.3.1.1(3) (as numbered in 2015 edition) and renumber the remaining sections.

Correct text should be: 12.3.1.1(3). Each component meeting the requirements of 4.10.3.1 shall betested by personnel.

See the related comment to move the initial testing of these components ahead of this section.This will cause section 12.3.6.1 to be renumbered.

ResponseMessage:




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6.3.10.1

Spacing of refrigerated LP-Gas containers designed to operate at greater than 15 psi (103 kPa) fromoccupied buildings, storage containers for flammable or combustible liquids, and lines of adjoiningproperty that can be built upon shall be in accordance with Table 6.3.10.1. [58:13.7.1]

Table 6.3.10.1 Minimum Distances for Refrigerated LP-Gas Containers That Operate at 15 psi (103 kPa)and Higher

Water Capacity per Container Aboveground Containers

gal m3 ft m

≤70,000 ≤265 75 23

70,001–90,000 265–341 100 30

90,001–120,000 341–454 125 38

120,001–200,000 454–757 200 61

200,001–1,000,000 757–3785 300 91

>1,000,000 >3785 400 122

[ 58: Table 13.7.1]




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Submittal Date: Tue Oct 11 15:37:12 EDT 2016

Committee Statement

CommitteeStatement:

The extract tag must be removed as the title was changed in the 2017 edition of NFPA 58,and the TC has not changed the title of this table.

ResponseMessage:


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7.1.1.5* Piping Cover.

7.1.1.5.1

New or replaced buried flammable liquid or gas piping with a design pressure below 20 percent of thepipe's specified minimum yield strength (SMYS) within the scope of this standard shall be installed witha minimum of 24 in. (610 mm) of cover in normal soil and a minimum of 18 in. (460 mm) of cover inconsolidated rock condition.

7.1.1.5.2

New or replaced buried flammable liquid or gas piping with design pressure above 20 percent of thepipe's specified minimum yield strength (SMYS) within the scope of this standard shall be installed witha minimum of 30 in. (760 mm) of cover in normal soil and a minimum of 18 in. (460 mm) of cover inconsolidated rock condition.

Supplemental Information

File Name Description

SR-17_A.7.1.1.5.docx




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Committee Statement

CommitteeStatement:

Resolved PI 28 proposed adding verbiage to section 7 to require the same requirements for depth ofcover over buried gas mains pipelines as Part 192.327 requires. There are current requirements inCFR 49 Part 192 for transmission gas pipelines, distribution gas mains and services minimize risk ofdamage to pipes from vehicle traffic or heavy equipment traffic. Damage of this type to buriedpipelines is not readily apparent when the occurrence happens, but can have catastrophicconsequences at some time after the damage takes place. Remaining silent on this issue does notexempt facilities from enforcement of Part 192.327 requirements as they are not in conflict with NFPA59 requirements and there for Part 192 can be enforced. It is more appropriate for the NFPA 59Standard to state the requirements for the safety of the piping and align with Part 192 minimumpipeline safety requirements.

ResponseMessage:



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SR-17, new annex

A.7.1.1.5

Where piping was buried prior to the requirements in 7.1.1.5, consideration should be given to marking

the buried piping.


7.1.1.6 Piping Cover.

7.1.1.6.1

New or replaced buried flammable liquid or gas piping design pressure above 20 percent of the pipe’sspecified minimum yield strength (SMYS) within the scope of this standard shall be installed with aminimum of 12 in. (300 mm) clearance from any other structure not associated with the piping.

7.1.1.6.2

New or replaced buried flammable liquid or gas piping design pressure below 20 percent of the pipe’sspecified minimum yield strength (SMYS) within the scope of this standard shall be installed withenough clearance from any other underground structure to allow proper maintenance and to protectagainst damage that might result from the pipe’s proximity to the other structures.




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Committee Statement

CommitteeStatement:

Resolved PI 29 proposed adding verbiage to section 7 to require the same requirements forclearance around buried gas pipelines as Part 192.325 requires. These are current requirements inCFR 49 Part 192 for transmission gas pipelines, distribution gas mains and services to allow propermaintenance activities to be performed. Remaining silent on this issue does not exempt facilities fromenforcement of Part 192.325 requirements as they are not in conflict with NFPA 59 requirements andtherefor Part 192 can be enforced. It is more appropriate for NFPA 59 to state the requirements forthe safety of the piping and align with Part 192 minimum pipeline safety requirements.

ResponseMessage:



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Second Revision No. 10-NFPA 59-2016 [ Section No. 7.8.1 ]

7.8.1

Refrigerated storage systems Refrigeration facilities shall be provided with sufficient capacity to maintaincontainers at a pressure not in excess of the operating pressure under design ambient conditions wherethe tank is sited and shall be provided with additional capacity for filling or standby service.




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7.9 Process Pressure Vessels.

Process pressure vessels shall be designed, fabricated, and code-stamped in accordance with theASME Boiler and Pressure Vessel Code , Section VIII, Division 1 or Division 2, or with CSA B51,Boiler, Pressure Vessel, and Pressure Piping Code .




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Committee Statement

CommitteeStatement:

The additional recognition of process pressure vessels that may be used and are not storagecontainers by definition should be identified, defined along with their design, and fabricationrequirements in the ASME BPVC.

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7.11.4.3*

The emergency shutoff valve(s) or backflow check valve(s) specified in 7.11.4.17.10.4.1 shall be installedin the plant facility piping so that any break resulting from a pull will occur on the hose or swivel-typepiping side of the connection while retaining intact the valves and piping on the plant facility side of theconnection.

Exception: Such anchorage shall not be required for the tank car side.




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7.11.4.4

All new installations and, by December 31, 2005, all existing installations shall have at least two clearlyidentified and easily accessible manually operated remote emergency shutoff devices. One shutoff deviceshall be located not less than 20 ft (6.1 m) nor more than 100 ft (30.5 m) in the path of egress from theemergency shutoff valve.




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Committee Statement

CommitteeStatement:

Restore the text removed by the first revision.

There are several retroactive requirements which appear in the code. A consistent and logicalmethod to address them should be chosen and applied to all references rather than treating eachone differently. Allowing the date to remain in the text until then will cause no harm.

ResponseMessage:



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]

A positive valving arrangement, such as a double-block-and-bleed, shall be installed close to the mixer toprevent backflow of gas into the air supply lines or of air into the LP-Gas system when the plant facility isnot in operation.




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10.2.3


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The For relief valve discharge pressure settings up to a maximum of 300 psig (2.1 MPag) for propane and250 psig (1.7 MPag) for butane, the minimum rate of discharge of pressure relief valves installed in ASMEcontainers shall be in accordance with Table 10.2.3 or shall be calculated using the following formula:

[10.2.3]

where:

F = minimum flow rate (SCFM air)

A = total outside surface area of container (ft2)

[ 58: 5.9.2.6]

Table 10.2.3 Minimum Required Rate of Discharge in Cubic Feet per Minute of Air at 120 Percent of theMaximum Permitted Start-to-Discharge Pressure for Safety Relief Devices to Be Used onNonrefrigerated Containers as a Function of Container Surface Area*

Surface Area (ft2)Flow Rate

(SCFM)Surface Area (ft2)

Flow Rate

(SCFM)Surface Area (ft2)

Flow Rate

(SCFM)

≤20 626 170 3620 600 10,170

25 751 175 3700 650 10,860

30 872 180 3790 700 11,550

35 990 185 3880 750 12,220

40 1100 190 3960 800 12,880

45 1220 195 4050 850 13,540

50 1330 200 4130 900 14,190

55 1430 210 4300 950 14,830

60 1540 220 4470 1000 15,470

65 1640 230 4630 1050 16,100

70 1750 240 4800 1100 16,720

75 1850 250 4960 1150 17,350

80 1950 260 5130 1200 17,960

85 2050 270 5290 1250 18,570

90 2150 280 5450 1300 19,180

95 2240 290 5610 1350 19,780

100 2340 300 5760 1400 20,380

105 2440 310 5920 1450 20,980

110 2530 320 6080 1500 21,570

115 2630 330 6230 1550 22,160

120 2720 340 6390 1600 22,740

125 2810 350 6540 1650 23,320

130 2900 360 6690 1700 23,900

135 2990 370 6840 1750 24,470

140 3080 380 7000 1800 25,050

145 3170 390 7150 1850 25,620

150 3260 400 7300 1900 26,180

155 3350 450 8040 1950 26,750

160 3440 500 8760 2000 27,310

165 3530 550 9470 — —

*This table is only applicable to containers holding propane with a maximum pressure of 300 psi or less orbutane with a maximum pressure of 250 psi or less.

For SI units: 1 SCFM = 0.0283 m3/min, 1 psi (gauge) = 6.9 kPa (gauge).


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Note: Flow rate in SCFM air.




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Committee Statement

CommitteeStatement:

FR-40 Section No. 10.2.3 which passed ballot should be overturned and revert back to the 2015text as the text that was struck as a result removed important relief valve sizing criteria addedduring the standards revision cycle, which lead to the issuance of the 2015 edition.

ResponseMessage:

Public Comment No. 4-NFPA 59-2016 [Section No. 10.2.3]


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Second Revision No. 6-NFPA 59-2016 [ Sections 12.3.3.1, 12.3.3.2, 12.3.3.3 ]

12.3.3.1

All new plants facilities shall meet all the requirements for corrosion control in Section 12.3 and12.10.2(3) .

12.3.3.2

All expanded, significantly modified plants facilities , or plants facilities replacing components containingLP-Gas (liquid or vapor state) shall meet the requirements for corrosion control in Section 12.3 and12.10.2(3) for expanded, modified, or replaced portions of the plant facility .

12.3.3.3

Corrosion control requirements shall be applied retroactively to existing plants facilities in accordance with12.3.3.3.1 through 12.3.3.3.3.

12.3.3.3.1

Atmospheric corrosion control requirements shall applied to existing facilities in accordance with12.3.3.3.1.1 and 12.3.3.3.1.2.

12.3.3.3.1.1

The following atmospheric corrosion control requirements shall be met within 1 year of the issuance of thiscode:

(1) Coating of exposed components in accordance with 4.9.1(2)

(2) Monitoring in accordance with 12.3.1.2

(3) Remedial measures in accordance with 12.3.2

(4) Recordkeeping in accordance with 12.10.2(3)

12.3.3.3.1.2

The following requirements for components covered by thermal insulation or fireproofing materials shall bemet within 3 years of issuance of this code:

(1) Coating in accordance with 4.9.1(2)

(2) Monitoring in accordance with 12.3.1.2.2



12.3.3.3.2

The following requirements for internal corrosion control shall be met within 1 year of the issuance of thiscode:

(1) Component monitoring in accordance with 12.3.1.3




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12.3.3.3.3

The following requirements for external corrosion control of buried or submerged components shall be metwithin 5 years of the issuance of this code:

(1) Install Installing a cathodic protection system in accordance with 4.8.2, 4.10.3, 4.10.4, 4.10.5, andSection 4.12

(2) Monitoring in accordance with 12.3.1.1






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]

Fire protection shall be provided for all utility gas plants LP-Gas facilities .




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13.2.4*

Where utilized, leak detection shall be permitted to be used in addition to, but not in lieu of, gasdetection.




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Committee Statement

CommitteeStatement:

The Public Input which initiated this addition refers to action taken by 59A, but 59A has not adopteda similar section. The original issue in 59A was whether to wire an RTD (temperature) sensor into afire detection system or a gas detection system. The action adopted for 59A was a new section:12.4.4 Leak detection. Leak detection shall activate an audible and visual alarm at the plant site andat a constantly attended location if the plant is not continuously attended.

ResponseMessage:

Public Comment No. 20-NFPA 59-2016 [Section No. 13.2.4]


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13.9.2.3

Such devices, when in place, shall prevent unauthorized operation of any of the container appurtenances,system facility valves, or equipment.




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Committee Statement

CommitteeStatement:


ResponseMessage:


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Second Revision No. 25-NFPA 59-2016 [ Section No. A.3.3.14 ]

Global SR-24

A.3.3.16 Fire Protection.

The term fire prevention covers measures directed at avoiding the inception of fire or the escalation of anincident following the accidental or inadvertent release of LP-Gas. Such measures could include productcontrol equipment and the insulation, mounding, or burial of containers.

The term fire detection covers equipment that detects the presence of fire or heat either to initiateautomated operation of the product control or other process equipment or to initiate local or remotealarms.

The term fire suppression covers means of supplying water or other agents providing for fire controlfireprotection, exposure protection, or fire extinguishment. The term fire protection is defined in NFPA 13 asa means of limiting the size of a fire by distribution of water so as to decrease the heat release rate andpre-wet adjacent combustibles while controlling ceiling gas temperatures to avoid structural damage.[58: A.3.3.24]




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Committee Statement

CommitteeStatement:

Simplification of fire protection terms in NFPA 59 necessitates further explanatory materialfor the term Fire Protection.

ResponseMessage:


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Second Revision No. 23-NFPA 59-2016 [ Section No. A.10.1 ]

A.10.1

Dilution effects from relief valves releasing hydrocarbon gases can vary dramatically depending onwhether the product released is vapor, mist, or liquid. Based on information provided in ANSI/API 521,Guide for Pressure-Relieving and Depressuring Systems, safety relieve relief valves that are in liquidservice when relieving do not entrain sufficient volumes of air to dilute the mixture to below LEL levels.Additional factors should be considered when establishing the electrical area classification andclassification distances near relief valves in liquid service lower flammable limit levels .

Experience has indicated that In contrast, for safety relief valves in vapor service only and those safetyrelief valves that emit a mist, a vertical and unimpeded vent of high-velocity hydrocarbon gases will entrainsufficient air within a very short distance so that the resultant plume will be diluted below the lowerflammable limit. This behavior is documented in ANSI/API 521. This document was based, in part, on anAPI-commissioned study by Battelle Memorial Institute, “The Effect of Velocity, Temperature, and GasMolecular Weight on Flammability Limits in Wind-Blown Jets of Hydrocarbon Gases.”

These reports clearly indicate that a vertical and unimpeded jet from a safety relief valve in vapor serviceonly and safety relief valves that emit a mist will be diluted below its lower flammable limit within 50 pipediameters of the issuing jet and that the effects of “wind-tilt” can be safely neglected if a 50 ft (15 m)horizontal clearance is provided between the jet and a source of ignition. A high velocity jet is defined asa jet having an exit velocity in excess of 100 ft/sec (30.5 m/sec), which is slightly more than an order ofmagnitude less than the acoustic velocity that can be anticipated at the throat of an operating relief valve.ANSI/API 521 also indicates that a partially open relief valve in vapor service will produce a velocitysufficient to achieve the necessary dilution.

Once such a mixture from a safety relief valve in vapor service only and those that emit a mist has beendiluted below its flammable limit, there are no known natural forces (including gravitational forces) that willcause the reconcentration of the LP-Gases so as to create a flammable cloud. The application of water,as either a fog or a heavy stream, will not hasten and can actually inhibit the dilution of the jet stream. It isrecommended that this information be included in any emergency procedure manual and that theresponding emergency services be made aware of this information These additional factors should beconsidered when establishing the electrical area classification and classification distances near reliefvalves in liquid service .




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Committee Statement

CommitteeStatement:

The revised text accepted by the TC at the first draft meeting makes subtle changes to text whichhas been unchanged for many years. Many readers will likely skim over the new text and assume itmatches their recollection of the previous version. A dramatically re-written section can provide thesame information and highlight the new information.

ResponseMessage:

Public Comment No. 18-NFPA 59-2016 [Section No. A.10.1]


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Second Revision No. 22-NFPA 59-2016 [ Section No. A.13.2.4 ]

A.13.2.4

Types of leak detection used to complement gas detection systems might include acoustic (ultrasonic),which detects small leak rates (mass/time); vapor cloud video surveillance cameras, which detect gascloud size; low temperature detectors, including resistance temperature detectors (RTD); and linear leakdetection, such as fiber-optic leak detection technology.




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Committee Statement

Committee Statement: The body text was removed, therefore the annex text should also be removed.

Response Message:

Public Comment No. 21-NFPA 59-2016 [Section No. A.13.2.4]


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Second Revision No. 29-NFPA 59-2016 [ Section No. F.1.2.2 ]

F.1.2.2 API Publications.

American Petroleum Institute, 1220 L Street, NW, Washington, DC 20005-4070.

ANSI/API 521, Guide for Pressure-Relieving and Depressuring Systems, 2007.

API RP 2003, Protection Against Ignitions Arising out of Static, Lightning, and Stray Currents, 2008edition.

“The Effect of Velocity, Temperature, and Gas Molecular Weight on Flammability Limits in Wind-BlownJets of Hydrocarbon Gases,” Battelle Memorial Institute, April 1, 1970.

API 625, Tank Systems for Refrigerated Liquefied Gas Storage , 2010.




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Committee Statement

CommitteeStatement:

“The Effect of Velocity, Temperature, and Gas Molecular Weight on Flammability Limits inWind-Blown Jets of Hydrocarbon Gases” is no longer referenced in the annex and has beenremoved, API 625 is now referenced and has been added.

ResponseMessage:


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Second Revision No. 30-NFPA 59-2016 [ Section No. F.3 ]

F.3 References for Extracts in Informational Sections.

NFPA 58, Liquefied Petroleum Gas Code, 2014 2017 edition.




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Committee Statement

Committee Statement: NFPA 58 reference is updated to the latest edition.

Response Message:


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second revision no. 15-nfpa 59-2016 [ global comment...

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