Ufc 3 430 05 2021
Ufc 3 430 05 2021
Ufc 3 430 05 2021
26 February 2021
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Use of the copyrighted material apart from this UFC must have the permission of the
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Indicate the preparing activity beside the Service responsible for preparing the document.
FOREWORD
The Unified Facilities Criteria (UFC) system is prescribed by MIL-STD 3007 and provides
planning, design, construction, sustainment, restoration, and modernization criteria, and applies
to the Military Departments, the Defense Agencies, and the DoD Field Activities in accordance
with USD (AT&L) Memorandum dated 29 May 2002. UFC will be used for all DoD projects and
work for other customers where appropriate. All construction outside of the United States is
also governed by Status of Forces Agreements (SOFA), Host Nation Funded Construction
Agreements (HNFA), and in some instances, Bilateral Infrastructure Agreements (BIA).
Therefore, the acquisition team must ensure compliance with the most stringent of the UFC, the
SOFA, the HNFA, and the BIA, as applicable.
UFC are living documents and will be periodically reviewed, updated, and made available to
users as part of the Services’ responsibility for providing technical criteria for military
construction. Headquarters, U.S. Army Corps of Engineers (HQUSACE), Naval Facilities
Engineering Command (NAVFAC), and Air Force Civil Engineer Center (AFCEC) are
responsible for administration of the UFC system. Defense agencies should contact the
preparing service for document interpretation and improvements. Technical content of UFC is
the responsibility of the cognizant DoD working group. Recommended changes with supporting
rationale may be sent to the respective DoD working group by submitting a Criteria Change
Request (CCR) via the Internet site listed below.
UFC are effective upon issuance and are distributed only in electronic media from the following
source:
• Whole Building Design Guide web site http://www.wbdg.org/ffc/dod.
Refer to UFC 1-200-01, DoD Building Code (General Building Requirements), for
implementation of new issuances on projects.
AUTHORIZED BY:
Document: UFC 3-430-05, Natural Gas and Liquefied Petroleum Gas (LPG)
Distribution Pipelines
Description: This UFC provides guidance to the design and installation of new or
modifications to existing distribution pipelines that convey natural gas, manufactured
gas, or LPG in the vapor phase, that are installed on Government owned property.
These requirements must be followed by the Government or its contractors when the
Government is the responsible operator of the distribution pipeline. Where the
Government is not the responsible operator, this UFC is intended to inform Government
personnel of the requirements typically implemented by the responsible operator of the
distribution pipeline.
Impact:
• This change increases the initial and maintenance costs of gas distribution
pipelines but ensures compliance with 49 CFR 192 in support of the
requirements for reporting to the Pipeline and Hazardous Material Safety
Administration (PHMSA). Proper application of these requirements also supports
the transfer of responsible operation of compliant gas distribution pipelines from
the Government to a Utility Privatization (UP) contractor or local gas provider.
Unification Issues
There are no unification issues with the guidance written herein.
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TABLE OF CONTENTS
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FIGURES
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CHAPTER 1 INTRODUCTION
This document does not cover building fuel gas piping, which is the piping system that
connects to the last downstream component of the distribution pipeline, either isolation
valve, service regulator or meter, and supplies fuel gas to individual appliances. Refer
to National Fire Protection Association (NFPA) 54, the International Code Council (ICC)
fuel gas code and Unified Facilities Guide Specifications (UFGS) 23 11 25 Facility Gas
Piping for guidance when installing building fuel gas piping.
This document does not cover systems used to convey LPG in its liquid phase. Refer to
49 CFR 195 and UFC 3-460-01 for liquid phase LPG pipelines and transfer systems.
Refer to NFPA 58, the ICC fuel gas code and UFGS 23 11 25 Facility Gas Piping for
guidance when installing a single LPG storage tank with LPG service to a single
building.
1-2 APPLICABILITY.
This UFC applies to all planning, design, design, construction, operations and
maintenance for the gas distribution pipeline and all of the appurtenances where the
DoD is designated as the responsible operator.
Regulations written in 49 CFR 192 apply to every part of gas pipelines from the point of
gas production to the point of connection of the service line components to a building’s
fuel gas piping system. An electronic version of 49 CFR 192 can be found at the
Electronic CFR website: https://ecfr.io/Title-49/cfr192_main. Within 49 CFR 192, three
distinct types of pipelines are described 1) Gathering Pipelines, 2) Transmission
Pipelines and 3) Distribution Pipelines. See Figure 1-1 for a graphical representation of
the 49 CFR 192 natural gas pipeline system. Gathering pipelines are not under the
authority or scope of this UFC. Transmission pipelines typically owned and operated by
gas suppliers and not covered by this UFC. Transmission lines installed on DoD
installations are under an easement from the DoD to a responsible owner.
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Gas pipelines for which the DoD is the responsible operator are typically classified as
Distribution Pipelines and are characterized as a pipeline that receives gas from a gas
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utility purveyor who delivers, meters, and regulates the pressure of gas supplied to the
distribution pipeline that is located on a DoD installation. See Figure 1-2 for a graphical
representation of the natural gas distribution pipeline.
49 CFR 192 also applies to LPG distribution pipelines that convey LPG in the vapor
phase. Piping that conveys liquid LPG is not covered under 49 CFR 192, but is
regulated by 49 CFR 195: Transportation of Hazardous Liquids by Pipeline. 49 CFR
195 §195.1 (b) (1) writes an exception to applicability for any hazardous liquid
transported in a gaseous state. This exception implements, by default, 49 CFR 192 as
the regulating document. 49 CFR 192 §192.11 refers to the vapor phase of LPG as
‘petroleum gas’ and requires that petroleum gas pipelines comply with 49 CFR 192 and
NFPA 58, with NFPA 58 prevailing in the event of conflict. NFPA 58 applies to liquid
LPG pipelines, liquid LPG storage containers, and pipelines that convey LPG in the
vapor phase. This UFC provides guidance for the vapor phase distribution pipeline and
the liquid storage container that serves that distribution pipeline. Please refer to UFC 3-
460-01 for guidance on liquid phase LPG piping systems.
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49 CFR 192 §192.1 (b) (5) allows two exceptions to applicability for any pipeline system
that transports only petroleum gas.
“(5) The regulations of 49 CFR 192 do not apply to a pipeline system that transports
petroleum gas or petroleum gas/air mixture to:
(i) Fewer than ten customers, if no portion of the system is located in a public place
– or –
(ii) A single customer, if the system is located entirely on the customer’s premises
(no matter if a portion of the system is located in a public place).”
Gas pipelines are described in 49 CFR 192 using the following nomenclature.
1-4.1 Gas.
Each time the term ‘Gas’ is used in this UFC, it is understood that the term applies to
natural gas, manufactured gas, liquefied petroleum gas in its vapor phase, and any
other flammable gas.
Gathering lines transport gas from a gas production facility to the transmission pipeline
or main. Gathering lines are not under the authority or control of DoD installations.
Transmission lines are typically owned and operated by gas suppliers and are not
operated by the DoD installation.
Distribution lines transport gas from the transmission line or LPG storage container to
each individual customer. Pipeline that operates at a hoop stress of 20% or more of the
specified minimum yield stress (SMYS) must also meet the requirements of a
transmission line.
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1-4.4.1 Main.
A main is defined as a distribution line that serves more than one service line. Note that
49 CFR 192, Subpart G appears to apply only to transmission pipelines because it is
entitled ‘General Construction Requirements for Transmission Lines and Mains’.
Whenever 49 CFR 192 discusses a Main, the requirement applies to the distribution
pipeline.
A service line is a distribution line that transports gas from a main to an individual
customer’s meter, regulator, or isolation valve upstream of the customer’s piping. Note
that this point of connection is the demarcation between the pipeline as governed by 49
CFR 192 and the fuel gas piping governed by NFPA 54.
A distribution system that operates with a gas pressure in the main that is higher than
the pressure provided to the customer.
A distribution system that operates with a gas pressure in the main that is substantially
the same as the pressure provided to the customer.
Refer to 49 CFR 192 §195.3 for the official definition of each of these terms.
Small natural gas distribution systems are sometimes designated as Master Meter
Systems (MMS). This designation is typically reserved for owners of apartment
buildings, trailer parks, or other types of property managers. The 49 CFR 192 refers to
MMO, the operator of an MMS, but does not provide clearly defined criteria for
determining who is and who is not an MMO. The reporting regulations for an MMO are
significantly less than the reporting regulations for the distribution pipeline operator;
however, the requirement to obtain and retain complete knowledge of the system
operated are nearly equal for each operator.
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The Pipeline and Hazardous Material Safety Administration (PHMSA) is assigned as the
administrator in 49 CFR 192 and is tasked with enforcing the regulations presented
therein. Transmission line operators and distribution line operators are required by the
regulations to report specific information to PHMSA. The reporting regulations are
different and more detailed for the transmission line operator than for the distribution
line operator. But, none the less, the distribution line operator is required to report to
PHMSA. These reporting requirements create the need for the pipeline operator to
obtain and retain complete knowledge of each pipeline segment and component
installed in the system that the operator is responsible for. Details of the plans,
procedures and reports that must be available for PHMSA review for distribution
pipelines are defined in 49 CFR 192, Subparts L and P. A more comprehensive
discussion of reporting requirements can be found in the January 2017 revision of
“Guidance Manual for Operators of Small Natural Gas Systems”, Chapter VIII, authored
by the Department of Transportation (DOT). Paragraph 1-3.7 of this UFC briefly
describes these reporting requirements to emphasize the importance of the detailed
design and construction submittal process necessary to support the DoD installation in
complying with the reporting regulations of 49 CFR 192.
State agencies may also enforce pipeline safety regulations that are more stringent than
the regulations presented in 49 CFR 192. Local municipalities, gas purveyors, and the
transmission line operator may also apply more stringent regulations. The distribution
line operator must know the regulations that apply to the distribution pipeline that he
operates and should transfer the requirements to design engineers and installing
contractors who perform work on this system.
It is necessary that the Designer of Record (DoR) for any distribution pipeline projects
such as construction, addition, rehabilitation, and repair on a DoD installation contact
the person or department responsible for operating the pipeline to understand the
requirements that apply.
All operators of gas pipelines are required to maintain a number of plans for safe
operation of the pipeline. Therefore, all information relative to work performed on gas
distribution pipelines installed on DoD installations must be provided to the responsible
operator through the design and construction process in order to support the ongoing
planning and reporting efforts required from that responsible operator. The Department
of Public Works (DPW)/Base Civil Engineer (BCE), a Utility Privatization (UP)
contractor, or a gas supplier is typically the responsible operator of gas distribution
pipelines located on DoD installations and should provide information on the distribution
pipeline as it exists and must receive complete information on all work performed.
The plans required from a distribution pipeline operator are listed below to indicate the
necessary thoroughness of the information that must be made available. Requirements
for developing these plans and reporting the information contained in the plans are
defined in 49 CFR 192.
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49 CFR 192 is divided into Subparts, each describing a specific area of concern. The
following sub-parts are not retroactive and apply to pipelines readied for service after 12
March 1971, or were replaced, relocated, or changed after 12 November 1970:
Subpart B – Materials
Subpart C – Pipe Design
Subpart D – Design of Pipeline Components
Subpart E – Welding of Steel in Pipelines
Subpart F – Joining of Materials other than by Welding
Sub part G – General Construction Requirements for Transmission Lines
Subpart H – Customer Meter, Services, Regulators, and Service Lines
Subpart J – Test Requirements
Subpart N – Qualification of Pipeline Personnel
The following subparts are retroactive and apply to all existing pipelines regardless of
date of construction:
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Subpart A – General
Subpart I – Requirements for Corrosion Control
Subpart K – Uprating
Subpart L – Operations
Subpart M – Maintenance
Subpart O – Gas Transmission Pipeline Integrity Management
Subpart P – Distribution Integrity Management
Pipelines on DoD installations must comply with the requirements of 49 CFR 192. A
comparable industrial standard is ASME B31.8, Gas Transmission and Distribution
Piping Systems. Although ASME B31.8 may appear to be an acceptable piping code
for compliant natural gas pipeline construction, it allows materials, components, and
construction practices that do not comply with 49 CFR 192. §192.7 specifies that use of
ASME B31.8 is approved only as referenced in §192.112(b) and §192.619(a).
As an industry standard, ASME B31.8 provides additional detail that is not found in the
Code of Federal Regulations (CFR). Therefore, ASME 31.8 is a very good reference
document and is recommended to help the reader better understand the material and
construction practices available from the natural gas industry. But 49 CFR 192 is the
defining requirements document and any decision made from information presented in
ASME B31.8 must be confirmed to comply with the requirements of 49 CFR 192.
1-7 GLOSSARY.
1-8 REFERENCES.
APPENDIX C contains a list of references used in this document. The publication date
of the code or standard is not included in this document. Unless otherwise specified,
the most recent edition of the referenced publication applies.
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Gas distribution pipelines will be planned carefully with due consideration for economy,
safety, and uniformity of pressure. The lines will be well-looped within the main area
and in all outlying areas whenever practicable and economically feasible to do so. It is
not always practicable to loop a supply line to an outlying area and then back into the
main system, but in such cases the objectionable effects of dead ends can often be
relieved to some extent by looping such line around the area it serves and then back
into itself.
Gas distribution pipelines will never be installed under a building. They will not be laid
in the same trench with other utilities to preclude the possibility of leaking gas following
along or collecting in other conduits and creating an explosion hazard. For the same
reason, gas lines will be above other utilities whenever they cross, if practicable.
Underground gas pipelines must be installed with the minimum clearance from other
underground structures as is specified in §192.325. Gas lines will not be laid under
paved streets or in other locations subject to heavy traffic whenever practicably
avoidable. Whenever it is necessary to locate gas lines in such locations, the lines will
be protected in accordance with (IAW) 49 CFR 192. Sufficient clearance must be
maintained between plastic mains and steam, hot water, power lines, and other sources
of heat, to avoid temperatures in excess of the rated temperature and pressure
combination of the pipe.
49 CFR 192, §192.5 classifies the location of a gas pipeline based on its proximity to
occupied buildings or frequently occupied outdoor locations. The location classification
ranges from Class 1 to Class 4 and signifies the level of risk and consequence to
human life in the event of pipeline failure. As population density increases, so the
location class number increases. The location classification is used in defining several
regulatory requirements for a given pipe segment.
The Designer of Record (DoR) of any project that modifies any segment of a gas
distribution pipeline on a DoD installation must obtain existing location classifications,
verify that the class meets §192.5, and identify the proper location class for all pipeline
segments modified or connected to in the project. Design drawings must indicate the
location classification for each pipe segment in the distribution pipeline. For projects on
DoD installations, all new or modified distribution pipeline must be location Class 3 to
minimize the impact that future building construction projects may have on existing
pipelines. Where connection is made to a pipe segment designed for a location class
other than Class 3, the drawings must identify the location of the change in class.
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The pipeline operator is responsible for maintaining the proper location classification for
each segment of pipe as additional buildings are constructed on the DoD installation.
Therefore, the DoR must coordinate the intended location classification with appropriate
DoD installation personnel.
The DoR must provide an engineering analysis, plans, and specifications that define the
work to be performed and all of the information that the installing contractor is required
to provide to the Government for a complete and functional installation that meets the
regulatory requirements of 49 CFR 192 and provides the Government Operator with all
information needed for proper reporting to the regulatory agency, for example PHMSA,
State agency.
Engineering analysis will be presented in diagram form showing all connected loads,
design flow rate, locations of valves, pressure regulators, and other pipeline devices,
actual operating pressure before and after each regulator, and any other appurtenance
required to control downstream pressure, relieve downstream pressure, or prevent
excess flow. A complete set of supporting calculations will be prepared.
2-2.2 Plans.
The plans will include a layout drawing showing the entire distribution system and detail
drawings clearly showing pipe sizes, the location of gas mains, service connections,
details for abandoning gas piping, mechanical couplings, valves, service taps,
regulators, and other appurtenances. ASME B31.8 requires that abandoned gas lines
be physically disconnected from gas sources. Shutoff valves are not an acceptable
means of disconnect.
2-2.3 Specifications.
The DoR must use UFGS 33 51 15 Natural-Gas / Liquefied Petroleum Gas Distribution
Pipelines to specify gas distribution pipeline work from the gas source (gas purveyor’s
meter and regulator) and LPG storage tank where applicable, to the point of connection
to building fuel gas piping. Be aware that UFGS 23 11 25 Facility Gas Piping specifies
the requirements from the point of connection to the distribution system to the
appliances.
Close-out submittals, SD-11, typically include items such as the as-built set of drawings
and specifications, test results, and project acceptance documents. Close-out
submittals for construction of distribution pipelines are required to include a complete
display of all information obtained during the construction process in order to support
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the ongoing efforts of the DoD Installation to comply with the documentation and
reporting tasks required by 49 CFR 192.
The following is a list of information that must be submitted at project close-out in order
to support the DoD Installation in obtaining and retaining information pertinent to
construction of distribution pipelines for which the DoD Installation is the operator:
The design for any new or modified gas pipeline must comply with 49 CFR 192, Subpart
C. For LPG (petroleum gas) pipelines, 49 CFR 192, §192.11 states that the
requirements of NFPA 58 prevail in case of conflict.
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Subpart C – Pipe Design, prescribes the minimum requirements for pipe design. Pipe
must be designed with sufficient wall thickness to withstand the internal pressure of the
gas without failure. The wall thickness must be increased or the pipe must be installed
with adequate protection to withstand the anticipated external forces and loads without
failure.
The design of a gas distribution pipeline installed on a DoD Installation will be based on
the sum of rated gas load of all connected appliances to the distribution pipeline in the
following proportions:
• Natural gas, more than 15 buildings: More than 80 percent of the full
connected appliance load.
• Natural gas, 15 buildings or fewer: 100 percent of the full connected
appliance load.
• LPG, vapor phase: 100 percent of the full connected appliance load
regardless of the system size.
2-3.2 Design Pressure for Steel Pipe.
The DoR must determine the design pressure of each pipe segment in accordance with
49 CFR 192, Subpart C.
Steel pipe design pressure is calculated using the equation presented in §192.105.
This equation uses the basic hoop stress equation with reduction factors for increased
temperature, type of longitudinal joint, and location classification. Each of the variables
used in the equation are defined in §192.107 through 115.
The yield strength of pipe is defined in the pipe specifications that are listed in 49 CFR
192, Appendix B, and is the Specified Minimum Yield Strength (SMYS) stated in the
Appendix B specification list for the pipe material used. Because pipe specifications not
listed in Appendix B are not allowed on Government DoD installations, alternative
means of determining yield strength are not allowed for new construction. These
alternative means may, however, be required for evaluating the design pressure
existing pipe.
Class 3 location is the minimum class allowed for all distribution pipelines on a DoD
Installation.
The DoR must determine the design pressure of each pipe segment in accordance with
49 CFR 192, Subpart C.
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Plastic pipe design pressure is calculated using the equation presented in §192.121.
This equation is a modified version of the basic hoop stress equation that uses terms
common in the plastic piping industry. The yield strength is the Hydrostatic Design
Basis (HDB) at or above the operating temperature of the pipe. The HDB is typically
found in the pipe specification that defines the particular type of plastic pipe.
The maximum allowed Standard Dimension Ratio (SDR) for plastic pipe installed on a
DoD installation is SDR-11. The SDR is the diameter of the pipe divided by the wall
thickness. SDR-11 represents the minimum wall thickness allowed on DoD
installations.
A design factor of 0.32 reduces the design pressure of polyethylene (thermoplastic) and
reinforced epoxy resin (thermosetting) pipe. A design factor of 0.40 reduces the design
pressure of polyamide-11 (PA-11) pipe.
Maximum design pressure for plastic pipe is limited by §192.121. 49 CFR 192 limits the
design pressure of plastic pipe to 100 pounds per square inch gauge (psig) with
exceptions in specific piping materials to allow higher pressures. These exceptions
must be thoroughly investigated and documented prior to providing plastic pipe in
systems with greater than 100 psig.
Note that ASTM F2945 for PA-11 states that heat fusion joining of PA-11 pipe and
fittings is not allowed to pipes and fittings made from any other thermoplastic materials.
Therefore, care should be taken when specifying a different type of plastic than has
been previously installed because of the complexity in connecting different plastic
materials.
The MAOP of the distribution pipeline is controlled by the responsible operator of that
distribution system, in accordance with 49 CFR 192. The DoR must obtain the MAOP
for the existing distribution system from this responsible operator prior to designing work
on the distribution pipeline. The MAOP must be included in the design calculations and
on the design drawings for each pipe segment connected to or installed in the project.
Maximum Allowable Operating Pressure (MAOP) for steel and plastic pipelines is
determined from the requirements stated in §192.619 thru 623, which prescribe the
MAOP for distribution mains and service lines respectively. MAOP, as determined
under §192.619 thru 623, is generally associated with the lowest of the design pressure
or a fraction of the test pressure that the pipe segment was initially tested to after
installation. The test pressure for Class 3 locations is 1.5 times the MAOP. Every pipe
segment must be tested IAW 49 CFR 192, Subpart J in order to substantiate the MAOP
determined under §192.619. It is recommended that new pipe be tested at the highest
pressure that is safely practical to set the MAOP of that pipe segment has high as safely
possible to prevent having to uprate in the future.
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MAOP for distribution mains is limited to 60 psig unless every service line connecting to
the distribution main contains devices installed for the purpose of protection against
over-pressurization IAW §192.197(c). These devices must limit the inlet pressure to the
service regulator by pressure regulation, flow relief, or isolation. ASME B31.8, para.
845 may be used as reference, as this reference provides additional information on
these overpressure devices, and all devices listed are included in 49 CFR 192.
Pipelines may have their pressure increased above a previously determined MAOP by
following the requirements of 49 CFR 192, Subpart K and logically determining a new
MAOP IAW §192.619. All pipe segments to be uprated must be tested to the
requirements of a new pipe of the same material installed in the same location.
The process required by 49 CFR 192, Subpart K is quite detailed, requiring much
research and field work before the pipeline pressure increase is allowed. Therefore, it is
recommended to initially test all pipelines to the highest test pressure that is safely
practical in order to prevent the need for uprating in the future.
Although 49 CFR 192.619 allows for determining alternative MAOP, this method is
difficult to implement due to the vast amount of information necessary to apply the
method. An acceptable alternative is to utilize §192.620 which provides the
requirements for determining and using an alternative MAOP. §192.620(b) (2) requires
that the pipeline segment that uses an alternative MAOP be constructed to meet the
additional design requirements of § 192.112. This section stipulates that only pipe
manufactured to API SPEC 5L may use the alternative MAOP. The requirements
further mandate several documented quality control manufacturing processes, which
are typically not available for existing systems and not cost effective for new systems.
Every pipe segment must be tested IAW 49 CFR 192, Subpart J in order to substantiate
the MAOP determined under §192.619. Tests are required to prove that the pipeline
does not leak and in specified cases must be strength tested for a specified duration.
For safety reasons, hydrostatic testing is preferred; however, 49 CFR 192 allows air,
inert gas, and even the natural gas source to be used under specific constraints. 49
CFR 192 does not allow the use of LPG in the vapor phase, a.k.a. petroleum gas, to be
used as a test media.
LPG pipelines operating under 49 CFR 192 must comply with the testing requirements
of 49 CFR 192, rather than testing described in NFPA 58.
The test pressure that applies to most distribution pipelines installed on DoD installation
are defined in the 2018 revision of 49 CFR 192 as follows:
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• §192.507 for steel pipelines operating at 100 psig or higher and less than
30% SMYS: Leak test between 100 psig and the pressure that creates
stress of 20% SMYS. Strength test at leak test pressure for duration of 1
hour.
• §192.509 for steel distribution mains operating below 100 psig: A
minimum leak test pressure of 90 psig for operating pressures of 1 psig or
greater. A minimum leak test pressure of 10 psig for operating pressures
less than 1 psig.
• §192.511 for steel service lines with operating stress less than 20%
SMYS: A minimum leak test pressure of 50 psig for operating pressures
from 1 to 40 psig. A minimum leak test pressure of 90 psig for operating
pressures greater than 40 psig.
• §192.513 for plastic distribution mains and service lines: Leak test
pressure at least 150% of the maximum operating pressure. Not less than
50 psig. Refer to §192.513 for further restrictions during testing.
Pneumatic leak testing must be performed IAW ASTM F2786. Hydrostatic
testing must be performed IAW ASTM F2164
For steel pipelines that operate at or above 100 psig, with a hoop stress less than 30%
of the SMYS, the rules presented in §192.507 must be applied using an appropriate test
pressure and inspection that discovers all leaks in the segment being tested. In the rare
case that a steel distribution pipeline operates with a hoop stress above 30% of the
SMYS, the reader should follow §192.505 for hydrostatic strength testing and leak
testing requirements.
Please refer to these 49 CFR 192 sections for updates to the required test pressures
and more detail of the required tests.
49 CFR 192 §513 requires that leak test on plastic distribution mains and service lines
be performed at a pressure at least 150% of the maximum operating pressure, but not
less than 50 psig. Refer to §192.513 for further restrictions during testing.
Leak testing of polyethylene and other plastic pipelines must be specified and
performed with an understanding of the effects that pressure has on the plastic material.
Pneumatic leak testing of polyethylene pipelines must be performed IAW ASTM F2786.
Hydrostatic testing of polyethylene pipelines must be performed IAW ASTM F2164.
Both of these documents prescribe procedures that limit the maximum test pressure to
1.5 times the design pressure of the weakest component. This limitation is in contrast
49 CFR 192 §513, which states that the maximum test pressure must not exceed 3
times the design pressure calculated in §192.121. This is because the two documents
define ‘design pressure’ differently.
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49 CFR 192 §121 uses the Hydrostatic Design Basis (HDB) of the particular material at
the testing temperature and a design factor of 0.32 to reduce the pipeline design
pressure.
ASTM F2786 uses the Hydrostatic Design Stress (HDS) of the particular material to
calculate the pressure rating of the pipeline and a temperature reduction factor to
reduce the pipeline maximum test pressure. ASTM F2164 uses the terms ‘design
pressure’ and ‘pressure rating’ synonymously.
It is recommended that the maximum test pressure be determined using the methods
presented in ASTM F2786 for pneumatic testing or ASTM F2164 for hydrostatic testing.
Although the ASTM and CFR methods produce the same maximum test pressure when
the pipe temperature is at 73° F, as the pipe temperature increases, 3 times the design
pressure as specified in 49 CFR 192 §513 exceeds the maximum test pressure
calculated from the ASTM methods.
In both pneumatic testing per ASTM F2786 and hydrostatic testing per ASTM F2164,
the length of time that the pipeline is pressurized above its MAOP is limited to 8 hours.
Therefore, from the start of pressurizing the pipeline, through the test phase, and ending
at depressurization of the pipeline, the total time duration must not exceed 8 hours. If
retesting is necessary, the pipeline must be allowed to relax at a pressure less than the
operating pressure for a duration of 8 hours before restarting the test.
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Containers used for storage of LPG in the liquid phase must comply with NFPA 58
requirements. Where piping systems are to be designed for filling LPG storage tanks,
please refer to UFC 3-460-01 for guidance in design of these specialized, LPG liquid
piping systems.
Pipe materials used in LPG distribution pipelines installed on a DoD installation must
comply with the material specifications listed in NFPA 58, with the exceptions of DoD
installations below.
Pipe materials used in natural gas and manufactured gas distribution pipelines installed
on a DoD installation must comply with the material specifications listed in 49 CFR 192,
Subpart B and Appendix B, with the following exceptions:
The following are exceptions to the materials listed in Appendix B of 49 CFR 192:
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Cast iron and ductile iron are restricted materials within 49 CFR 192. Cast and ductile
iron should not be used in natural or manufactured gas distribution pipelines on DoD
installations. Where existing cast iron or ductile iron pipe is installed, the DoR must
make every effort to know all details of its installation and any rehabilitation that has
been performed. The construction documents created by the DoR that connect to the
existing cast iron or ductile iron pipe must require the installing contractor to perform all
inspections and tests and make all necessary enhancements or take all necessary
precautions required by 49 CFR 192. The following information is identified from the
2018 revision of 49 CFR 192, but is not inclusive of all restrictions. NFPA 58 does not
allow cast iron pipe or pressure containing components constructed from cast iron to be
used in LPG pipelines. NFPA 58 does not allow ductile iron pipe to be used in LPG
pipelines, but does allow metallic fittings and pressure containing components to be
constructed from ductile iron that meets ASTM A395/A395M.
The following apply to existing cast iron or ductile iron natural or manufactured gas
pipelines as stated:
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• §192.621 limits the operating pressure of cast iron pipe segment with
unreinforced bell and spigot connections to 25 psig.
• §192.753 (a) requires all bell and spigot connections in pipe segments
operating at pressures higher than 25 psig to be sealed with mechanical
leak clamps or equivalent. For pipe segments operating at 25 psig or
below, the connection must be sealed IAW §192.753. (b) if the connection
is exposed for any reason.
• Existing cast iron connections that are sealed with a gasket and retained
by a follower ring are qualified under §192.275 but are restricted in MAOP.
• Cast iron flanges must be cast integrally into the pipe, fitting, or valve and
must conform to ASME B16.1.
• Neither cast iron nor ductile iron pipe that is less than 6” nominal pipe size
(NPS) may be used as a service line, per §192.373.
• Requirements of §192.557 must be met before the operating pressure of a
cast iron or ductile iron pipe segment is increased above its previously
established MAOP.
• Ductile iron components are typically allowed to operate at 80% of their
rated pressure at temperature.
In addition, §192.489 requires the replacement of cast and ductile iron piping that shows
general graphitization might cause the pipe to fracture or leak. Only localized
graphitization may be repaired. Several other paragraphs throughout 49 CFR 192 place
requirements on construction practices that may be required when modifying a
distribution pipeline that is constructed from cast iron or ductile iron. The reader is
cautioned to pay particular attention to all design elements when modifying an existing
pipeline constructed of these materials.
3-3.1 Fittings.
Fittings used on steel pipe must be butt welded or flanged and be rated for the
operating pressure and temperature of the distribution pipeline. Butt weld fittings should
be factory made wrought steel per ASME B16.9 with butt weld ends per ASME B16.25.
Flanges should comply with ASME B16.5 and MSS SP-44.
Threaded fittings complying with ASME B1.20.1 may be used above ground only, due to
the corrosion potential when installed underground. Threaded fittings must have at
least the minimum metal thickness required for the operating pressure and temperature
of the system.
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Socket weld fittings must not be used in natural gas, manufactured gas, or LPG
distribution pipelines installed on DoD installations for the reasons listed hereinafter.
Socket weld fittings are connected by a fillet weld, which is not a full penetration weld
and cannot be confirmed by nondestructive testing to meet pull-out requirements. The
socket weld fitting also contains a void between the pipe and fitting that can be a site for
contaminant, corrosion, natural gas, and petroleum distillate to reside, undetected.
Branch connections must be designed for both pressure and temperature requirements
and mechanical strength. Tee fittings should be used for branch connections where
practical. Welded branch connection must be designed and constructed to ensure that
the strength of the pipeline system is not reduced, taking into account the stresses in
the remaining pipe wall due to the opening in the pipe or header, the shear stresses
produced by the pressure acting on the area of the branch opening, and any external
loadings due to thermal movement, weight, and vibration.
Mechanical fittings used to make a hot taps must be qualified to withstand the maximum
anticipated operating pressure and temperature of the pipeline.
Mechanical compression joints are allowed to connect plastic pipe only in locations
where other fitting types are not feasible. When compression joints are utilized, they
must be installed in accordance with the requirements of 49 CFR § 192.281(e). Proof of
satisfying the design requirements must be provided by a knowledgeable third party
such as a representative of the compression joints manufacturer. The manufacturer of
the mechanical compression fitting must certify that the fitting is intended for the specific
gas service, that the gasket is compatible with the type of plastic specified, and that a
rigid tubular internal stiffener, not split tubular, is incorporated in the design. The
manufacturer must provide the part number, serial number and year made for each
mechanical fitting used on a DoD installation and the contractor must submit this
information along with the GIS Location and date of installation for the Government’s
permanent record.
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3-3.2 Valves.
Steel valves installed in natural and manufactured gas distribution pipelines must
comply with API SPEC 6D. Although ASME B16.34 is the basis for all valves specified
in API SPEC 6D, §192.145 mandates that all steel valves in a natural gas pipelines
comply with the requirements of API SPEC 6D, which adds substantial additional
features and testing over and above the requirements of ASME B16.34. Metallic valves
installed in metallic distribution pipelines conveying LPG must comply with UL 125.
Valves installed in polyethylene distribution pipelines that convey natural gas,
manufactured gas, or LPG must comply with ASTM D2513 and ASME B16.40. Valves
installed in polyamide distribution pipelines that convey natural gas, manufactured gas,
or LPG must comply with ASTM F2945 and ASME B16.40.
Cast iron, malleable iron, and ductile iron are restricted materials for use in natural or
manufactured gas pipelines within 49 CFR 192 and should not be used in valve shell
construction on Government DoD installations. Although these materials have been
used in the past, and may qualify under certain conditions, these materials should not
be used in new natural gas pipelines installed on Government DoD installations. These
materials are not qualified for use at compressor stations.
Valves must be installed in the distribution pipeline in the locations required by 49 CFR
§192.181 and as described below:
Where a gas source that is at higher pressure than the MAOP of a distribution pipeline,
and is connected to that distribution pipeline, a pressure regulator is required and a
pressure relieving device or pressure limiting device that meets the requirements of
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§192.199 and §192.201 is required to protect the distribution pipeline from over
pressurization that could result from failure of the upstream pressure control or of failure
of some other type.
Four different types of pressure regulators are used in the design of a natural gas or
manufactured gas systems, which are as follows:
• Appliance regulator: allowed in the fuel gas piping defined by NFPA 54,
but not qualified to operate in a 49 CFR 192 distribution pipeline.
• Line regulator: allowed in the fuel gas piping defined by NFPA 54, but not
qualified to operate in a 49 CFR 192 distribution pipeline.
• Main regulators: supplied by a qualified manufacturer of regulators
intended for use in a distribution system.
• Service regulator: qualified by AGA ANSI B109.4 to be installed at the
end of service line, with an isolation valve.
Each service regulator installed on a service line intended to regulate the pressure of
fuel gas supplied to a consumer must comply with §192.197(c)(3). This paragraph
requires that a pressure relief device be installed to protect the piping system connected
to the low-pressure side of the regulator. This pressure relief device may be built into
the service regulator or may be a separate relief valve installed downstream of the
service regulator. The relief device must be capable of relieving downstream pressure,
at the rated regulator flow, to prevent over pressurization of the consumer’s fuel gas
piping. Even though §192.197(a) allows regulators with specified characteristics, but
having no pressure relief, to be installed on distribution systems that operate at 60 psig
or less, this practice is not recommended for DoD installations because future pressure
increases would require major infrastructure rehabilitation.
3-3.3.2 Natural and Manufactured Gas Pressure Relief and Limiting Devices.
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The pressure relieving or limiting device must be designed IAW §192.199. The capacity
of the pressure relieving and limiting device must be IAW §192.201. In all cases where
natural gas is vented from a pressure relieving or limiting device to the atmosphere, the
vent must be constructed to prevent blockage by rain, snow, ice, insects, or vermin and
must discharge safely to the environment without undue hazard.
The pressure of LPG in the vapor phase must be reduced and regulated when leaving
the LPG liquid container in accordance with NFPA 58, paragraph 5.10. This pressure
regulator must be one of the two stage regulator combinations specified in NFPA 58,
paragraph 5.10, and must contain the required pressure relief device or overpressure
shutoff device. The regulators used in an LPG distribution pipeline must comply with UL
144. Do not use line pressure regulators per ANSI Z21.80, or appliance regulators per
ANSI Z21.18 in an LPG distribution pipeline. Line and appliance regulators belong in
the fuel gas piping system as specified in NFPA 54 with specific reference to NFPA 58.
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Customer meters, service regulators and service lines must comply with the
requirements of 49 CFR 192, Subpart H. This subpart addresses the allowed locations
for installation, the requirement for protection against damage, and the elimination of
stress on the piping system.
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3-3.4.1 Meters.
§192.359 requires that all new meters be tested by the manufacturer at a shell pressure
of not less than 10 psig. Meters may not be operated at a pressure higher than 67% of
the manufacturer’s shell test pressure. A rebuilt or repaired tinned steel meter may not
be operated at more than 50% of the pressure used to test the meter after rebuilding or
repairing. Gas meters that comply with AGA ANSI B109 are qualified for natural gas,
manufactured gas and LPG in the vapor phase, but the manufacturer must know which
gas will be metered. LPG in the vapor phase may or may not require metering when it
is supplied from a distribution pipeline to multiple customers on a DoD installation.
Please coordinate with the contracting officer of the project to determine the
Government’s desire for metering of LPG.
3-3.4.2 Regulators.
The service regulator that reduces the natural or manufactured gas pressure to the
meter and the customer’s fuel gas piping system are described in paragraph 3-2.3 of
this UFC. Refer to NFPA 54 for specific usage of line pressure regulators that reduce 2
psig gas supply to appliance regulator inlet pressure and appliance regulators.
The term ‘service regulator’ does not apply to LPG distribution pipelines. Required
regulators are described in paragraph 3-2.3 of this UFC. Refer to NFPA 58 and NFPA
54 for specific usage of line pressure regulators that reduce 2 psig LPG vapor supply to
appliance regulator inlet pressure and appliance regulators.
Each steel service line to be operated at less than 100 psig must be constructed of pipe
designed for a minimum of 100 psig. Additional requirements are defined in §192.361
through §192.379. Exception to §192.375 is that a plastic service line may not be
exposed above grade level on a DoD installation. An anode less riser must be used to
bring a plastic service line from below grade to a steel pipe serving the isolation valve,
service regulator, and meter.
An EFV must be installed on all new or replaced single and branched service lines that
serve single-family residences where the service line operates at 10 psig or greater.
EFVs are also required to be installed on multifamily residences, and small commercial
entities consuming gas volumes not exceeding 1,000 standard cubic feet per hour
(SCFH). The EFV must comply with the requirements of §192.381 and close upon
detection of flow in excess of the anticipated maximum flow through the service line.
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Sizing an EFV requires knowing the maximum gas demand of all the appliances
connected to the service line. The potential for adding future gas burning equipment
should also be considered.
3-3.6 Vaults.
Vaults must be structurally sound, designed to minimize entrance of water, and must
not be drained to any other underground structure. Vaults serving as access to natural
gas distribution pipelines must comply with §192.183 through §192.189. Where plastic
pipe passes through a vault must be encased in ASTM A53/A53M minimum schedule
40 steel pipe that is properly protected from corrosion and vented.
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Methods used to install natural gas distribution pipelines must be proven to provide a
durable, gas-tight system. All pipe joints made in the system must be made in
accordance with qualified written procedures and by personnel qualified by training and
testing that have been proven by test or experience to produce strong, gas-tight joints.
The DoD installation must include these qualified written procedures and personnel
qualifications in its operations and maintenance manual. It is therefore required that the
installing contractor provide a qualified written procedure and personnel qualifications
for each joint made in the distribution pipeline.
Welding of steel pipelines must comply with the requirements of 49 CFR 192, Subpart
E.
The installing contractor must submit for Government approval, a written procedure for
welding steel pipe and fittings installed in the distribution pipeline. Welding procedures
must be qualified under API STD 1104, Section 5, Section 12, or Appendix A or under
the ASME/BPVC SEC IX as written in §192.225. The contractor must make sure that
welding is performed in accordance with these established written welding procedures
that have been qualified and tested to produce quality welds.
Welders must be qualified IAW API STD 1104, Section 6, Section 12, or Appendix A or
under the ASME/BPVC SEC IX as written in §192.227. The contractor must submit to
the Government, proof of each welder’s current certification of qualification. Welders
qualifications must further comply with the limitations specified in §192.229, which
include qualification intervals and methods of qualification.
Welders of pipe segments and components intended to serve natural gas compressors
must be qualified under the destructive test requirements of the applicable API STD
1104 sections.
All welds must be inspected by a person that is qualified by training and experience to
ensure welding is performed by certified welders, using a qualified written procedure,
and has produced acceptable welds under API STD 1104, Section 9 or Appendix A,
which will not be used to accept cracks. In accordance with §192.243, and minimum
location class 3 for DoD installations, 100% of welds on pipelines and components
operating at a hoop stress of 20% or more of the SMYS must be nondestructively
tested.
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The installing contractor must submit for Government approval, a qualified, written
procedure for joining plastic materials obtained from the manufacturer of the plastic pipe
and fittings installed in the system. The procedure must have been proven to make
strong, gas-tight joints by passing the tests specified in §192.283. Vendors who cannot
provide this qualified jointing procedure must be disqualified from supplying materials
for the work. The contractor must make sure that each joint is made in accordance with
these Government approved procedures. Any contract that purchases plastic pipe for
use in the natural gas distribution system must disallow the purchase of plastic pipe
from any manufacturer or supplier that does not certify qualified joining procedures for
the pipe. It is the DoD installation’s responsibility to verify that the contractor follows
these written joining procedures for each type of pipe and fitting used.
The contract documentation must require the contractor to train, test, and qualify each
person performing work on the natural gas distribution system located on a DoD
installation in accordance with 49 CFR 192, Subpart F. No person may make a plastic
pipe joint unless that person has been qualified under the pipe manufacturer’s written
joining procedure by making a specimen joint that passes inspection and test. The
specimen joint used to qualify the joiner must be visually examined during and after
joining and found to have the same appearance as a joint or photograph of a joint that is
acceptable under the procedure. In the case of heat fusion, the specimen must be cut
into at least three longitudinal straps, each of which is:
All pipelines must be installed IAW 49 CFR 192. Joining of new pipe to existing pipe
must be in a manner approved in 49 CFR 192.
Where a distribution pipeline passes under a roadway or a railroad, the pipeline must be
encased in steel pipe that protected from corrosion. If the casement is not vented it
must be sufficiently strong to contain the operating pressure of the gas without
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Distribution mains must have minimum cover of 24” or be otherwise protected from
external loads and excavation damage. In accordance with §192.361, the part of the
service line installed in a public right-of-way must have minimum cover of 18”. This
service line is allowed to have a minimum cover of 12” once it has passed onto private
property. For DoD installations, it is recommended that the 12” cover apply only to
single family dwellings but could be safely expanded to duplexes and quad-plexes. A
minimum 18” cover is required for service lines serving any other type of building on a
DoD Installation.
Plastic pipe installed in a distribution pipeline must be installed below grade and must
be continuously supported in suitable compacted soil to prevent movement after
installation. Ensure that the installation has sufficient slack to prevent pullout due to
thermal contraction. Inspect pipe and fittings for damage prior to backfilling. If the pipe
has a scratch or cut that exceeds 10% of the wall thickness, it must be replaced.
Plastic pipelines must be installed with sufficient clearance from any item that may
increase the temperature of the plastic pipe segment, to prevent degradation of the pipe
strength. These items may include, but are not limited to, hot water piping, steam
piping, condensate piping, and electrical equipment. Where proximity cannot be
avoided, the DoR must design adequate protection to prevent pipe temperature
increase. Where temperature increase of the plastic pipe cannot be avoided, the DoR
must reduce the design pressure of the plastic pipe by using a Hydrostatic Design Basis
value for a temperature that is higher than the actual anticipated temperature.
Aboveground steel pipe must be securely supported and protected from vehicular
collisions. Steel pipe must be painted for corrosion protection.
Where steel pipe is required for below grade installations the pipe must be coated with
an approved anti corrosion coating and must be cathodically protect IAW 49 CFR 192,
Subpart I. The pipe must be continuously supported by properly compacted material.
Where connections are made to existing underground steel pipe, the contractor must
inspect the existing pipe for corrosion and take remedial action IAW 49 CFR 192
Subpart I if corrosion is found.
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Metallic pipelines installed underground must be protected from corrosion IAW 49 CFR
192, Subpart I, which includes both an approved anti corrosion coating per §192.461
and a cathodic protection system in compliance with the requirements of §192.463.
The DoR for any project installing or connecting to existing underground metallic pipe
must support the distribution pipeline operator’s efforts to control corrosion through
proper design and requiring the installing contractor to do the following:
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Compressor Stations are not defined but are only described within 49 CFR 192. 49
CFR 192 and ASME B31.8 provide the following specific requirements for piping that
connects to compressor stations:
• Steel pipe from the gas distribution main to the compressor, 49 CFR 192
§192.229 and ASME B31.8, 843.4.
• Cast iron components must not be used in compressor station piping
systems, 49 CFR 192 §192.145 (e) and ASME B31.8, 831.1.
• Welders must be qualified based on destructive test requirements of API
1104. 49 CFR 192 §192.229 and ASME B31.8, 823.2.2.
• Butt welds must be 100% tested by non-destructive methods such as
radiography, 49 CFR 192 §192.243, ASME B31.8, 826.3.
6-2 FUEL GAS BOOSTER COMPRESSORS.
Requirements for construction of natural gas compressors are defined in the following
American Petroleum Institute (API) documents:
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The Whole Building Design Guide provides additional information and discussion on
practice and facility design, including a holistic approach to integrated design of
facilities.
The WBDG provides access to all Construction Criteria Base (CCB) criteria, standards
and codes for the DoD Military Departments, National Aeronautics and Space
Administration (NASA), and others. These include, Unified Facilities Criteria (UFC),
Unified Facilities Guide Specifications (UFGS), Performance Technical Specifications
(PTS), design manuals, and specifications. For approved Government employees, it
also provides access to non-government standards.
A-2 GUIDANCE.
In absence of installation specific directive instructions and guidance, follow gas pipeline
safety regulations defined in the DOT manual as it applies to natural gas systems and
operators of natural gas master meter systems. The pipeline safety regulations require
operators of natural gas systems to: deliver gas safely and reliably to customers;
provide training and written instruction for employees; establish written procedures to
minimize the hazards resulting from natural gas pipeline emergencies; and, keep
records of inspection and testing.
Designers and operators should check with the pipeline safety agency in their state to
determine:
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APPENDIX B GLOSSARY
B-1 ACRONYMS
PA-11 Polyamide-11
PE Polyethylene
SD Submittal Description
UP Utility Privatization
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APPENDIX C REFERENCES
www.aga.org
AGA ANSI B109.4, Self-Operated Diaphragm-Type Natural Gas Service Regulators for
Nominal Pipe Size 1¼ inches (32 mm) and Smaller with Outlet Pressures of 2 psig
(13.8 kPa) and Less
www.ansi.org
www.api.org
API RP 686, Recommended Practice for Machinery Installation and Installation Design
API STD 618, Reciprocating Compressors for Petroleum, Chemical, and Gas Industry
Services
API-ASME Code, Unfired Pressure Vessels for Petroleum Liquids and Gases
www.asme.org
ASME B16.1, Gray Iron Pipe Flanges and Flanged Fittings Classes 25, 125, and 250
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ASME B16.40, Manually Operated Thermoplastic Gas Shutoffs and Valves in Gas
Distribution Systems
ASME Section VIII, Rules for the Construction of Unfired Pressure Vessels
ASME/BPVC SEC IX, ASME Boiler and Pressure Vessel Code, Section IX
www.astm.org
ASTM A53/A53M, Standard Specification for Pipe, Steel, Black and Hot-Dipped, Zinc-
Coated, Welded and Seamless
ASTM D2513, Standard Specification for Polyethylene (PE) Gas Pressure Pipe, Tubing,
and Fittings
ASTM D2517, Standard Specification for Reinforced Epoxy Resin Gas Pressure Pipe,
Tube, and Fittings
ASTM F2945, Standard Specification for Polyamide 11 Gas Pressure Pipe, Tubing, and
Fittings
ASTM F2164, Standard Practice for Field Leak Testing of Polyethylene (PE) and
Crosslinked Polyethylene (PEX) Pressure Piping Systems Using Hydrostatic
Pressure
ASTM F2786, Standard Practice for Field Leak Testing of Polyethylene (PE) Pressure
Piping Systems Using Gaseous Testing Media Under Pressure (Pneumatic Leak
Testing)
http://msshq.org
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www.nfpa.org
NFPA 37, Standard for the Installation and Use of Stationary Combustion Engines and
Gas Turbines
www.phmsa.dot.gov
www.ul.com
UL 125, UL Standard for Safety Flow Control Valves for Anhydrous Ammonia and LP-
Gas
https://www.wbdg.org/ffc/dod/unified-facilities-criteria-ufc
https://www.wbdg.org/ffc/dod/unified-facilities-guide-specifications-ufgs
www.archives.gov
49 CFR 192, Transportation of Natural and Other Gas by Pipeline: Minimum Safety
Standards
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