**Subpart A--General**

Sec.

193.2001 Scope of part.

193.2005 Applicability.

193.2007 Definitions.

193.2009 Rules of regulatory construction.

193.2011 Reporting.

193.2013 Incorporation by reference.

193.2017 Plans and procedures.

193.2019 Mobile and temporary LNG facilities.

**Subpart B--Siting Requirements**

193.2051 Scope.

193.2057 Thermal radiation protection.

193.2059 Flammable vapor-gas dispersion protection.

193.2067 Wind forces.

**Subpart C--Design**

193.2101 Scope.

193.2119 Records.

**Impoundment Design and Capacity**

193.2155 Structural requirements.

193.2161 Dikes, general.

193.2167 Covered systems.

193.2173 Water removal.

193.2181 Impoundment capacity; LNG storage tanks.

**LNG Storage Tanks**

193.2187 Nonmetallic membrane liner.

**Subpart D--Construction**

193.2301 Scope.

193.2303 Construction acceptance.

193.2304 Corrosion control overview.

193.2321 Nondestructive tests.

**Subpart E--Equipment**

193.2401 Scope.

**Control Systems**

193.2441 Control center.

193.2445 Sources of power.

**Subpart F--Operations**

193.2501 Scope.

193.2503 Operating procedures.

193.2505 Cooldown.

193.2507 Monitoring operations.

193.2509 Emergency procedures.

193.2511 Personnel safety.

193.2513 Transfer procedures.

193.2515 Investigations of failures.

193.2517 Purging.

193.2519 Communication systems.

193.2521 Operating records.

**Subpart G--Maintenance**

193.2601 Scope.

193.2603 General.

193.2605 Maintenance procedures.

193.2607 Foreign material.

193.2609 Support systems.

193.2611 Fire protection.

193.2613 Auxiliary power sources.

193.2615 Isolating and purging.

193.2617 Repairs.

193.2619 Control systems.

193.2621 Testing transfer hoses.

193.2623 Inspecting LNG storage tanks.

193.2625 Corrosion protection.

193.2627 Atmospheric corrosion control.

193.2629 External corrosion control; buried or submerged components.

193.2631 Internal corrosion control.

193.2633 Interference currents.

193.2635 Monitoring corrosion control.

193.2637 Remedial measures.

193.2639 Maintenance records.

**Subpart H--Personnel Qualifications and Training**

193.2701 Scope.

193.2703 Design and fabrication.

193.2705 Construction, installation, inspection, and testing.

193.2707 Operations and maintenance.

193.2709 Security.

193.2711 Personnel health.

193.2713 Training; operations and maintenance.

193.2715 Training; security.

193.2717 Training; fire protection.

193.2719 Training; records.

**Subpart I--Fire Protection**

193.2801 Scope.

**Subpart J--Security**

193.2901 Scope.

193.2903 Security procedures.

193.2905 Protective enclosures.

193.2907 Protective enclosure construction.

193.2909 Security communications.

193.2911 Security lighting.

193.2913 Security monitoring.

193.2915 Alternative power sources.

193.2917 Warning signs.

**Authority:** 49 U.S.C. 5103, 60102, 60103, 60104, 60108, 60109, 60110,
60113, 60118; and 49 CFR 1.53.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-10,
61 FR 18512, Apr. 26, 1996; Amdt. 193-13, 62 FR 8402, Feb. 25, 1997,
Amdt. 193-17, 65 FR 10950, March 1, 2000; Amdt. 193-18, 69 FR 11330,
March 10, 2004\]

**Subpart A--General**

**§193.2001 Scope of part.**

\(a\) This part prescribes safety standards for LNG facilities used in
the transportation of gas by pipeline that is subject to the pipeline
safety laws (49 U.S.C. 60101 *et seq.*) and Part 192 of this chapter.

\(b\) This part does not apply to:

\(1\) LNG facilities used by ultimate consumers of LNG or natural gas.

\(2\) LNG facilities used in the course of natural gas treatment or
hydrocarbon extraction which do not store LNG.

\(3\) In the case of a marine cargo transfer system and associated
facilities, any matter other than siting pertaining to the system or
facilities between the marine vessel and the last manifold (or in the
absence of a manifold, the last valve) located immediately before a
storage tank.

\(4\) Any LNG facility located in navigable waters (as defined in
Section 3(8) of the Federal Power Act (16 U.S.C. 796(8)).

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-1,
45 FR 57402, Aug. 28, 1980; Amdt. 193-10, 61 FR 18512, Apr. 26, 1996\]

**§193.2005 Applicability.**

\(a\) Regulations in this part governing siting, design, installation,
or construction of LNG facilities (including material incorporated by
reference in these regulations) do not apply to LNG facilities in
existence or under construction when the regulations go into effect.

\(b\) If an existing LNG facility (or facility under construction before
March 31, 2000 is replaced, relocated or significantly altered after
March 31, 2000, the facility must comply with the applicable
requirements of this part governing, siting, design, installation, and
construction, except that:

\(1\) The siting requirements apply only to LNG storage tanks that are
significantly altered by increasing the original storage capacity or
relocated, and

\(2\) To the extent compliance with the design, installation, and
construction requirements would make the replaced, relocated, or altered
facility incompatible with the other facilities or would otherwise be
impractical, the replaced, relocated, or significantly altered facility
may be designed, installed, or constructed in accordance with the
original specifications for the facility, or in another manner subject
to the approval of the Administrator.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-1,
45 FR 57418, Aug. 28, 1980; Amdt. 193-2, 45 FR 70390, Oct. 23, 1980;
Amdt. 193-8, 58 FR 14519, Mar. 18, 1993, Amdt. 193-17, 65 FR 10950,
March 1, 2000; Amdt. 193-18, 69 FR 11330, March 10, 2004\]

**§193.2007 Definitions.**

As used in this part:

***Administrator*** means the Administrator, Pipeline and Hazardous
Materials Safety Administration or his or her delegate.

***Ambient vaporizer*** means a vaporizer which derives heat from
naturally occurring heat sources, such as the atmosphere, sea water,
surface waters, or geothermal waters.

***Cargo transfer system*** means a component, or system of components
functioning as a unit, used exclusively for transferring hazardous
fluids in bulk between a tank car, tank truck, or marine vessel and a
storage tank.

***Component*** means any part, or system of parts functioning as a
unit, including, but not limited to, piping, processing equipment,
containers, control devices, impounding systems, lighting, security
devices, fire control equipment, and communication equipment, whose
integrity or reliability is necessary to maintain safety in controlling,
processing, or containing a hazardous fluid.

***Container*** means a component other than piping that contains a
hazardous fluid.

***Control system*** means a component, or system of components
functioning as a unit, including control valves and sensing, warning,
relief, shutdown, and other control devices, which is activated either
manually or automatically to establish or maintain the performance of
another component.

***Controllable emergency*** means an emergency where reasonable and
prudent action can prevent harm to people or property.

***Design pressure*** means the pressure used in the design of
components for the purpose of determining the minimum permissible
thickness or physical characteristics of its various parts. When
applicable, static head shall be included in the design pressure to
determine the thickness of any specific part.

***Determine*** means make an appropriate investigation using scientific
methods, reach a decision based on sound engineering judgment, and be
able to demonstrate the basis of the decision.

***Dike*** means the perimeter of an impounding space forming a barrier
to prevent liquid from flowing in an unintended direction.

***Emergency*** means a deviation from normal operation, a structural
failure, or severe environmental conditions that probably would cause
harm to people or property.

***Exclusion zone*** means an area surrounding an LNG facility in which
an operator or government agency legally controls all activities in
accordance with §193.2057 and §193.2059 for as long as the facility is
in operation.

***Fail-safe*** means a design feature which will maintain or result in
a safe condition in the event of malfunction or failure of a power
supply, component, or control device.

***g*** means the standard acceleration of gravity of 9.806 meters per
second^2^ (32.17 feet per second^2^).

***Gas,*** except when designated as inert, means natural gas, other
flammable gas, or gas which is toxic or corrosive.

***Hazardous fluid*** means gas or hazardous liquid.

***Hazardous liquid*** means LNG or a liquid that is flammable or toxic.

***Heated vaporizer*** means a vaporizer which derives heat from other
than naturally occurring heat sources.

***Impounding space*** means a volume of space formed by dikes and
floors which is designed to confine a spill of hazardous liquid.

***Impounding system*** includes an impounding space, including dikes
and floors for conducting the flow of spilled hazardous liquids to an
impounding space.

***Liquefied natural gas*** or ***LNG*** means natural gas or synthetic
gas having methane (CH~4~) as its major constituent which has been
changed to a liquid.

***LNG facility*** means a pipeline facility that is used for liquefying
natural gas or synthetic gas or transferring, storing, or vaporizing
liquefied natural gas.

***LNG plant*** means an LNG facility or system of LNG facilities
functioning as a unit.

***m^3^*** means a volumetric unit which is one cubic meter, 6.2898
barrels, 35.3147 ft.^3^, or 264.1720 U.S. gallons, each volume being
considered as equal to the other.

***Maximum allowable working pressure*** means the maximum gage pressure
permissible at the top of the equipment, containers or pressure vessels
while operating at design temperature.

***Normal operation*** means functioning within ranges of pressure,
temperature, flow, or other operating criteria required by this part.

***Operator*** means a person who owns or operates an LNG facility.

***Person*** means any individual, firm, joint venture, partnership,
corporation, association, state, municipality, cooperative association,
or joint stock association and includes any trustee, receiver, assignee,
or personal representative thereof.

***Pipeline facility*** means new and existing piping, rights-of-way,
and any equipment, facility, or building used in the transportation of
gas or in the treatment of gas during the course of transportation.

***Piping*** means pipe, tubing, hoses, fittings, valves, pumps,
connections, safety devices or related components for containing the
flow of hazardous fluids.

***Storage tank*** means a container for storing a hazardous fluid.

***Transfer piping*** means a system of permanent and temporary piping
used for transferring hazardous fluids between any of the following:
Liquefaction process facilities, storage tanks, vaporizers, compressors,
cargo transfer systems, and facilities other than pipeline facilities.

***Transfer system*** includes transfer piping and cargo transfer
system.

***Vaporization*** means an addition of thermal energy changing a liquid
to a vapor or gaseous state.

***Vaporizer*** means a heat transfer facility designed to introduce
thermal energy in a controlled manner for changing a liquid to a vapor
or gaseous state.

***Waterfront LNG plant*** means an LNG plant with docks, wharves,
piers, or other structures in, on, or immediately adjacent to the
navigable waters of the United States or Puerto Rico and any shore area
immediately adjacent to those waters to which vessels may be secured and
at which LNG cargo operations may be conducted.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-1,
45 FR 57402, Aug. 28, 1980; Amdt. 193-2, 45 FR 70390, Oct. 23, 1980;
Amdt. 193-10, 61 FR 18512, Apr. 26, 1996, Amdt. 193-17, 65 FR 10950,
March 1, 2000; Amdt. 193-18, 68 FR 11748, Mar. 12, 2003; 70 FR 11135,
Mar. 8, 2005\]

**§193.2009 Rules of regulatory construction.**

\(a\) As used in this part:

\(1\) **\"Includes\"** means including but not limited to;

\(2\) **\"May\"** means is permitted to or is authorized to;

\(3\) **\"May not\"** means is not permitted to or is not authorized to;
and

\(4\) **\"Shall\"** or \"**must**\" is used in the mandatory and
imperative sense.

\(b\) In this part:

\(1\) Words importing the singular include the plural; and

\(2\) Words importing the plural include the singular.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980\]

**§193.2011 Reporting.**

Leaks and spills of LNG must be reported in accordance with the
requirements of Part 191 of this chapter.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980\]

**§193.2013 Incorporation by reference.**

\(a\) Any document or portion thereof incorporated by reference in this
part is included in this part as though it were printed in full. When
only a portion of a document is referenced, then this part incorporates
only that referenced portion of the document and the remainder is not
incorporated. Applicable editions are listed in paragraph (c) of this
section in parentheses following the title of the referenced material.
Earlier editions listed in previous editions of this section may be used
for components manufactured, designed, or installed in accordance with
those earlier editions at the time they were listed. The user must refer
to the appropriate previous edition of 49 CFR for a listing of the
earlier editions.

\(b\) All incorporated materials are available for inspection in the
Pipeline and Hazardous Materials Safety Administration, 400 Seventh
Street, SW., Washington, DC, or at the National Archives and Records
Administration (NARA). For information on the availability of this
material at NARA, call 202-741-6030 or go to:
*http://www.archives.gov/federal_register/code_of_federal_regulations/IBR_locations.html*.

Documents incorporated by reference are available from the publishers as
follows:

A. American Gas Association (AGA), 400 North Capitol Street, NW.,
Washington, DC 20001.

B. American Society of Civil Engineers (ASCE), Parallel Centre, 1801
Alexander Bell Drive, Reston, VA 20191-4400.

C. ASME International (ASME), Three Park Avenue, New York, NY
10016-5990.

D. Gas Technology Institute (GTI), 1700 S. Mount Prospect Road, Des
Plaines, IL 60018.

E. National Fire Protection Association (NFPA), 1 Batterymarch Park,
P.O. Box 9101, Quincy, MA 02269-9101.

\(c\) Documents incorporated by reference.

+---------------------------------------------+------------------------+
| Source and name of referenced material      | 49 CFR reference       |
+---------------------------------------------+------------------------+
| A. American Gas Association (AGA):          | §§ 193.2513; 193.2517; |
|                                             | 193.2615.              |
| \(1\) "Purging Principles and               |                        |
| Practices,\'\'(3rd edition, 2001).          |                        |
+---------------------------------------------+------------------------+
| B. American Society of Civil Engineers      | §193.2067.             |
| (ASCE):                                     |                        |
|                                             |                        |
| \(1\) SEI/ASCE 7-02 "Minimum Design Loads   |                        |
| for Buildings and Other Structures,\'\'     |                        |
| (2002 edition).                             |                        |
+---------------------------------------------+------------------------+
| C. ASME International (ASME):               | §193.2321.             |
|                                             |                        |
| \(1\) ASME Boiler and Pressure Vessel Code, |                        |
| Section VIII, Division 1, "Rules for        |                        |
| Construction of Pressure Vessels,\'\' (2004 |                        |
| edition, including addenda through July 1,  |                        |
| 2005).                                      |                        |
+---------------------------------------------+------------------------+
| \(2\) ASME Boiler and Pressure Vessel Code, | §193.2321.             |
| Section VIII, Division 2, "Rules for        |                        |
| Construction of Pressure                    |                        |
| Vessels\--Alternative Rules,\'\' (2004      |                        |
| edition, including addenda through July 1,  |                        |
| 2005)                                       |                        |
+---------------------------------------------+------------------------+
| .D. Gas Technology Institute (GTI):         | §193.2057.             |
|                                             |                        |
| \(1\) GRI-89/0176 "LNGFIRE: A Thermal       |                        |
| Radiation Model for LNG Fires,\'\' (June    |                        |
| 29, 1990).                                  |                        |
+---------------------------------------------+------------------------+
| \(2\) GTI-04/0049 (April 2004) "LNG Vapor   | §193.2059.             |
| Dispersion Prediction with the DEGADIS 2.1: |                        |
| Dense Gas Dispersion Model for LNG Vapor    |                        |
| Dispersion\'\'.                             |                        |
+---------------------------------------------+------------------------+
| \(3\) GRI-96/0396.5 "Evaluation of          | §193.2059.             |
| Mitigation Methods for Accidental LNG       |                        |
| Releases, Volume 5: Using FEM3A for LNG     |                        |
| Accident Consequence Analyses,\'\' (April   |                        |
| 1997).                                      |                        |
+---------------------------------------------+------------------------+
| E. National Fire Protection Association     | §§ 193.2019; 193.2051; |
| (NFPA):                                     | 193.2057; 193.2059;    |
|                                             | 193.2101; 193.2301;    |
| \(1\) NFPA 59A (2001) "Standard for the     | 193.2303; 193.2401;    |
| Production, Storage, and Handling of        | 193.2521; 193.2639;    |
| Liquefied Natural Gas (LNG).\'\'.           | 193.2801.              |
+---------------------------------------------+------------------------+

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-18,
69 FR 11330, March 10, 2004; 70 FR 11135, Mar. 8, 2005; Amdt. 193-19, 71
FR 33402, June 9, 2006\]

**§193.2017 Plans and procedures.**

\(a\) Each operator shall maintain at each LNG plant the plans and
procedures required for that plant by this part. The plans and
procedures must be available upon request for review and inspection by
the Administrator or any State Agency that has submitted a current
certification or agreement with respect to the plant under the pipeline
safety laws (49 U.S.C. 60101 *et seq.*). In addition, each change to the
plans or procedures must be available at the LNG plant for review and
inspection within 20 days after the change is made.

\(b\) The Administrator or the State Agency that has submitted a current
certification under section 5(a) of the Natural Gas Pipeline Safety Act
with respect to the pipeline facility governed by an operator\'s plans
and procedures may, after notice and opportunity for hearing as provided
in 49 CFR 190.237 or the relevant State procedures, require the operator
to amend its plans and procedures as necessary to provide a reasonable
level of safety.

\(c\) Each operator must review and update the plans and procedures
required by this part---

\(1\) When a component is changed significantly or a new component is
installed; and

\(2\) At intervals not exceeding 27 months, but at least once every 2
calendar years.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980; as amended by Amdt. 193-3A,
50 FR 4578, Amdt. 193-7, 56 FR 31087, July 9, 1991; Amdt. 193-10, 61 FR
18512, Apr. 26, 1996; Amdt. 193-18, 69 FR 11330, March 10, 2004\]

**§193.2019 Mobile and temporary LNG facilities.**

\(a\) Mobile and temporary LNG facilities for peakshaving application,
for service maintenance during gas pipeline systems repair/alteration,
or for other short term applications need not meet the requirements of
this part if the facilities are in compliance with applicable sections
of NFPA 59A (incorporated by reference, *see* §193.2013).

\(b\) The state agency having jurisdiction over pipeline safety in the
State in which the portable LNG equipment is to be located must be
provided with a location description for the installation at least 2
weeks in advance, including to the extent practical, the details of
siting, leakage containment or control, fire fighting equipment, and
methods employed to restrict public access, except that in the case of
emergency where such notice is not possible, as much advance notice as
possible must be provided.

\[Amdt. 193-13, 62 FR 8402, Feb. 25, 1997 as amended by Amdt. 193.13A,
62 FR 36465, Jul. 8, 1997; Amdt. 193-14, 62 FR 41311, Aug. 1, 1997;
Amdt. 193-18, 69 FR 11330, March 10, 2004\]

**Subpart BSiting Requirements**

**§193.2051 Scope.**

Each LNG facility designed, constructed, replaced, relocated or
significantly altered after March 31, 2000 must be provided with siting
requirements in accordance with the requirements of this part and of
NFPA 59A (incorporated by reference, *see* §193.2013). In the event of a
conflict between this part and NFPA 59A, this part prevails.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 amended by Amdt. 193-1, 45
FR 57402, Aug. 28, 1980, Amdt. 193-17, 65 FR 10950, March 1, 2000; Amdt.
193-18, 69 FR 11330, March 10, 2004\]

**§193.2055 General.**

An LNG facility must be located at a site of suitable size, topography,
and configuration so that the facility can be designed to minimize the
hazards to persons and offsite property resulting from leaks and spills
of LNG and other hazardous fluids at the site. In selecting a site, each
operator shall determine all site-related characteristics which could
jeopardize the integrity and security of the facility. A site must
provide ease of access so that personnel, equipment, and materials from
offsite locations can reach the site for fire fighting or controlling
spill associated hazards or for evacuation of personnel.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 amended by Amdt. 193-17, 65
FR 10950, March 1, 2000\]

**§193.2057 Thermal radiation**

**protection.**

Each LNG container and LNG transfer system must have a thermal exclusion
zone in accordance with section 2.2.3.2 of NFPA 59A (incorporated by
reference, *see* §193.2013) with the following exceptions:

\(a\) The thermal radiation distances shall be calculated using Gas
Research Institute\'s (GRI) report GRI-89/0176 (incorporated by
reference, *see* §193.2013), which is also available as the "LNGFIRE
III**"** computer model produced by GRI. The use of other alternate
models which take into account the same physical factors and have been
validated by experimental test data shall be permitted subject to the
Administrator\'s approval.

\(b\) In calculating exclusion distances, the wind speed producing the
maximum exclusion distances shall be used except for wind speeds that
occur less than 5 percent of the time based on recorded data for the
area.

\(c\) In calculating exclusion distances, the ambient temperature and
relative humidity that produce the maximum exclusion distances shall be
used except for values that occur less than five percent of the time
based on recorded data for the area.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-1,
45 FR 57402, Aug. 28, 1980; Amdt. 193-3A, 50 FR 4578, Amdt. 193-13, 62
FR 8402, Feb. 25, 1997; Amdt. 193-16, 63 FR 37500, July 13, 1998, Amdt.
193-17, 65 FR 10950, March 1, 2000; Amdt. 193-18, 69 FR 11330, March 10,
2004\]

**§193.2059 Flammable vapor-gas**

**dispersion protection.**

Each LNG container and LNG transfer system must have a dispersion
exclusion zone in accordance with sections 2.2.3.3 and 2.2.3.4 of NFPA
59A (incorporated by reference, *see* §193.2013) with the following
exceptions:

\(a\) Flammable vapor-gas dispersion distances must be determined in
accordance with the model described in the Gas Research Institute report
GRI-89/0242 (incorporated by reference, *see* §193.2013), "LNG Vapor
Dispersion Prediction with the DEGADIS Dense Gas Dispersion Model.**"**
Alternatively, in order to account for additional cloud dilution which
may be caused by the complex flow patterns induced by tank and dike
structure, dispersion distances may be calculated in accordance with the
model described in the Gas Research Institute report GRI 96/0396.5
(incorporated by reference, *see* §193.2013), "Evaluation of Mitigation
Methods for Accidental LNG Releases. Volume 5: Using FEM3A for LNG
Accident Consequence Analyses**"**. The use of alternate models which
take into account the same physical factors and have been validated by
experimental test data shall be permitted, subject to the
Administrator\'s approval.

\(b\) The following dispersion parameters must be used in computing
dispersion distances:

\(1\) Average gas concentration in air = 2.5 percent.

\(2\) Dispersion conditions are a combination of those which result in
longer predicted downwind dispersion distances than other weather
conditions at the site at least 90 percent of the time, based on figures
maintained by National Weather Service of the U.S. Department of
Commerce, or as an alternative where the model used gives longer
distances at lower wind speeds, Atmospheric Stability (Pasquill Class)
F, wind speed = 4.5 miles per hour (2.01 meters/sec) at reference height
of 10 meters, relative humidity = 50.0 percent, and atmospheric
temperature = average in the region.

\(3\) The elevation for contour (receptor) output H = 0.5 meters.

\(4\) A surface roughness factor of 0.03 meters shall be used. Higher
values for the roughness factor may be used if it can be shown that the
terrain both upwind and downwind of the vapor cloud has dense vegetation
and that the vapor cloud height is more than ten times the height of the
obstacles encountered by the vapor cloud.

\(c\) The design spill shall be determined in accordance with section
2.2.3.5 of NFPA 59A (incorporated by reference, *see* §193.2013).

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-1,
45 FR 57402, Aug. 28, 1980; Amdt. 193-3A, 50 FR 4578, Amdt. 193-13, 62
FR 8402, Feb. 25, 1997; Amdt. 193-15, 63 FR 7721, Feb. 17, 1998; Amdt.
193-16, 63 FR 37500, July 13, 1998, Amdt. 193-17, 65 FR 10950, March 1,
2000; Amdt. 193-18, 69 FR 11330, March 10, 2004\]

**§193.2067 Wind forces.**

\(a\) LNG facilities must be designed to withstand without loss of
structural or functional integrity;

\(1\) The direct effect of wind forces;

\(2\) The pressure differential between the interior and exterior of a
confining, or partially confining, structure; and

\(3\) In the case of impounding systems for LNG storage tanks, impact
forces and potential penetrations by wind borne missiles.

\(b\) The wind forces at the location of the specific facility must be
based on one of the following:

\(1\) For shop fabricated containers of LNG or other hazardous fluids
with a capacity of not more than 70,000 gallons, applicable wind load
data in SEI/ASCE 7-02 (incorporated by reference, *see* §193.2013).

\(2\) For all other LNG facilities:

\(i\) An assumed sustained wind velocity of not less than 150 miles per
hour, unless the Administrator finds a lower velocity is justified by
adequate supportive data; or

\(ii\) The most critical combination of wind velocity and duration, with
respect to the effect on the structure, having a probability of
exceedance in a 50-year period of 0.5 percent or less, if adequate wind
data are available and the probabilistic methodology is reliable.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-1,
45 FR 57402, Aug. 28, 1980; Amdt. 193-3A, 50 FR 4578, Amdt. 193-8, 58 FR
14519, Mar. 18, 1993; Amdt. 193-16, 63 FR 37500, July 13, 1998, Amdt.
193-17, 65 FR 10950, March 1, 2000; Amdt. 193-19, 71 FR 33402, June 9,
2006\]

**Subpart CDesign**

**§193.2101 Scope.**

Each LNG facility designed after March 31, 2000 must comply with
requirements of this part and of NFPA 59A (incorporated by reference,
*see* §193.2013). In the event of a conflict between this part and NFPA
59A, this part prevails.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-17,
65 FR 10950, March 1, 2000; Amdt. 193-18, 69 FR 11330, March 10, 2004\]

**[Materials]{.smallcaps}**

**§193.2119 Records.**

Each operator shall keep a record of all materials for components,
buildings, foundations, and support systems, as necessary to verify that
material properties meet the requirements of this part. These records
must be maintained for the life of the item concerned.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-1,
45 FR 57402, Aug. 28, 1980\]

**[Impoundment Design and Capacity]{.smallcaps}**

**§193.2155 Structural requirements.**

\(a\) The structural members of an impoundment system must be designed
and constructed to prevent impairment of the system\'s performance
reliability and structural integrity as a result of the following:

\(1\) The imposed loading from--

\(i\) Full hydrostatic head of impounded LNG;

\(ii\) Hydrodynamic action, including the effect of any material
injected into the system for spill control;

\(iii\) The impingement of the trajectory of an LNG jet discharged at
any predictable angle; and,

\(iv\) Anticipated hydraulic forces from a credible opening in the
component or item served, assuming that the discharge pressure equals
design pressure.

\(2\) The erosive action from a spill, including jetting of spilling
LNG, and any other anticipated erosive action including surface water
runoff, ice formation, dislodgment of ice formation, and snow removal.

\(3\) The effect of the temperature, any thermal gradient, and any other
anticipated degradation resulting from sudden or localized contact with
LNG.

\(4\) Exposure to fire from impounded LNG or from sources other than
impounded LNG.

\(5\) If applicable, the potential impact and loading on the dike due
to--

\(i\) Collapse of the component or item served or adjacent components;
and

\(ii\) If the LNG facility adjoins the right-of-way of any highway or
railroad, collision by or explosion of a train, tank car, or tank truck
that could reasonably be expected to cause the most severe loading.

\(b\) An LNG storage tank must not be located within a horizontal
distance of one mile (1.6 km) from the ends, or ¼ mile (0.4 km) from the
nearest point of a runway, whichever is longer. The height of LNG
structures in the vicinity of an airport must also comply with Federal
Aviation Administration requirements in 14 CFR Section 1.1.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-17,
65 FR 10950, March 1, 2000\]

**§193.2161 Dikes; general.**

An outer wall of a component served by an impounding system may not be
used as a dike unless the outer wall is constructed of concrete.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-17,
65 FR 10950, March 1, 2000\]

**§193.2167 Covered systems.**

A covered impounding system is prohibited except for concrete wall
designed tanks where the concrete wall is an outer wall serving as a
dike.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-17,
65 FR 10950, March 1, 2000\]

**§193.2173 Water removal**.

\(a\) Impoundment areas must be constructed such that all areas drain
completely to prevent water collection. Drainage pumps and piping must
be provided to remove water from collecting in the impoundment area.
Alternative means of draining may be acceptable subject to the
Administrator\'s approval.

\(b\) The water removal system must have adequate capacity to remove
water at a rate equal to 25% of the maximum predictable collection rate
from a storm of 10-year frequency and 1-hour duration, and other natural
causes. For rainfall amounts, operators must use the "Rainfall Frequency
Atlas of the United States**"** published by the National Weather
Service of the U.S. Department of Commerce.

\(c\) Sump pumps for water removal must--

\(1\) Be operated as necessary to keep the impounding space as dry as
practical; and

\(2\) If sump pumps are designed for automatic operation, have redundant
automatic shutdown controls to prevent operation when LNG is present.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-17,
65 FR 10950, March 1, 2000\]

**§193.2181 Impoundment capacity; LNG storage tanks.**

Each impounding system serving an LNG storage tank must have a minimum
volumetric liquid impoundment capacity of:

\(a\) 110 percent of the LNG tank\'s maximum liquid capacity for an
impoundment serving a single tank;

\(b\) 100 percent of all tanks or 110 percent of the largest tank\'s
maximum liquid capacity, whichever is greater, for the impoundment
serving more than one tank; or

\(c\) If the dike is designed to account for a surge in the event of
catastrophic failure, then the impoundment capacity may be reduced to
100 percent in lieu of 110 percent.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-17,
65 FR 10950, March 1, 2000\]

**[LNG Storage Tanks]{.smallcaps}**

**§193.2187 Nonmetallic membrane liner.**

A flammable nonmetallic membrane liner may not be used as an inner
container in a storage tank.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-17,
65 FR 10950, March 1, 2000\]

**Subpart D****Construction**

**§193.2301 Scope.**

Each LNG facility constructed after March 31, 2000 must comply with
requirements of this part and of NFPA 59A (incorporated by reference,
*see* §193.2013). In the event of a conflict between this part and NFPA
59A, this part prevails.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-17,
65 FR 10950, March 1, 2000; Amdt. 193-18, 69 FR 11330, March 10, 2004\]

**§193.2303 Construction acceptance.**

No person may place in service any component until it passes all
applicable inspections and tests prescribed by this subpart and NFPA 59A
(incorporated by reference, *see* §193.2013).

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-17,
65 FR 10950, March 1, 2000; Amdt. 193-18, 69 FR 11330, March 10, 2004\]

**§193.2304 Corrosion control overview.**

\(a\) Subject to paragraph (b) of this section, components may not be
constructed, repaired, replaced, or significantly altered until a person
qualified under §193.2707(c) reviews the applicable design drawings and
materials specifications from a corrosion control viewpoint and
determines that the materials involved will not impair the safety or
reliability of the component or any associated components.

\(b\) The repair, replacement, or significant alteration of components
must be reviewed only if the action to be taken--

\(1\) Involves a change in the original materials specified;

\(2\) Is due to a failure caused by corrosion; or

\(3\) Is occasioned by inspection revealing a significant deterioration
of the component due to corrosion.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-17,
65 FR 10950, March 1, 2000\]

**§193.2321 Nondestructive tests.**

The butt welds in metal shells of storage tanks with internal design
pressure above 15 psig must be radiographically tested in accordance
with the ASME Boiler and Pressure Vessel Code (Section VIII Division 1),
except that hydraulic load bearing shells with curved surfaces that are
subject to cryogenic temperatures, 100 percent of both longitudinal (or
meridional) and circumferential (or latitudinal) welds must be
radiographically tested.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-8,
58 FR 14519, Mar. 18, 1993; Amdt. 193-10, 61 FR 18512, Apr. 26, 1996;
Amdt. 193-16, 63 FR 37500, July 13, 1998, Amdt. 193-17, 65 FR 10950,
March 1, 2000\]

**Subpart E--Equipment**

**§193.2401 Scope.**

After March 31, 2000, each new, replaced, relocated or significantly
altered vaporization equipment, liquefaction equipment, and control
systems must be designed, fabricated, and installed in accordance with
requirements of this part and of NFPA 59A (incorporated by reference,
*see* §193.2013). In the event of a conflict between this part and NFPA
59A, this part prevails.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-17,
65 FR 10950, March 1, 2000; Amdt. 193-18, 69 FR 11330, March 10, 2004\]

**[Control Systems]{.smallcaps}**

**§193.2441 Control center.**

Each LNG plant must have a control center from which operations and
warning devices are monitored as required by this part. A control center
must have the following capabilities and characteristics:

\(a\) It must be located apart or protected from other LNG facilities so
that it is operational during a controllable emergency.

\(b\) Each remotely actuated control system and each automatic shutdown
control system required by this part must be operable from the control
center.

\(c\) Each control center must have personnel in continuous attendance
while any of the components under its control are in operation, unless
the control is being performed from another control center which has
personnel in continuous attendance.

\(d\) If more than one control center is located at an LNG plant, each
control center must have more than one means of communication with each
other center.

\(e\) Each control center must have a means of communicating a warning
of hazardous conditions to other locations within the plant frequented
by personnel.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980\]

**§193.2445 Sources of power.**

\(a\) Electrical control systems, means of communication, emergency
lighting, and firefighting systems must have at least two sources of
power which function so that failure of one source does not affect the
capability of the other source.

\(b\) Where auxiliary generators are used as a second source of
electrical power--

\(1\) They must be located apart or protected from components so that
they are not unusable during a controllable emergency; and

\(2\) Fuel supply must be protected from hazards.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980\]

# Subpart FOperations

**§193.2501 Scope.**

This subpart prescribes requirements for the operation of LNG facilities

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2503 Operating procedures.**

Each operator shall follow one or more manuals of written procedures to
provide safety in normal operation and in responding to an abnormal
operation that would affect safety. The procedures must include
provisions for:

\(a\) Monitoring components or buildings according to the requirements
of §193.2507.

\(b\) Startup and shutdown, including for initial startup, performance
testing to demonstrate that components will operate satisfactory in
service.

\(c\) Recognizing abnormal operating conditions.

\(d\) Purging and inserting components according to the requirements of
§193.2517.

\(e\) In the case of vaporization, maintaining the vaporization rate,
temperature and pressure so that the resultant gas is within limits
established for the vaporizer and the downstream piping.

\(f\) In the case of liquefaction, maintaining temperatures, pressures,
pressure differentials and flow rates, as applicable, within their
design limits for:

\(1\) Boilers;

\(2\) Turbines and other prime movers;

\(3\) Pumps, compressors, and expanders;

\(4\) Purification and regeneration equipment; and

\(5\) Equipment within cold boxes.

\(g\) Cooldown of components according to the requirements of §193.2505.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980; as amended by Amdt. 193-18,
69 FR 11330, March 10, 2004\]

**§193.2505 Cooldown.**

\(a\) The cooldown of each system of components that is subjected to
cryogenic temperatures must be limited to a rate and distribution
pattern that keeps thermal stresses within design limits during the
cooldown period, paying particular attention to the performance of
expansion and contraction devices.

\(b\) After cooldown stabilization is reached, cryogenic piping systems
must be checked for leaks in areas of flanges, valves, and seals.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2507 Monitoring operations.**

Each component in operation or building in which a hazard to persons or
property could exist must be monitored to detect fire or any malfunction
or flammable fluid that could cause a hazardous condition. Monitoring
must be accomplished by watching or listening from an attended control
center for warning alarms, such as gas, temperature, pressure, vacuum,
and flow alarms, or by conducting an inspection or test at intervals
specified in the operating procedures.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980; as amended by Amdt. 193-18,
69 FR 11330, March 10, 2004\]

**§193.2509 Emergency procedures.**

\(a\) Each operator shall determine the types and places of emergencies
other than fires that may reasonably be expected to occur at an LNG
plant due to operating malfunctions, structural collapse, personnel
error, forces of nature, and activities adjacent to the plant.

\(b\) To adequately handle each type of emergency identified under
paragraph (a) of this section and each fire emergency, each operator
shall follow one or more manuals of written procedures. The procedures
must provide for the following:

\(1\) Responding to controllable emergencies, including notifying
personnel and using equipment appropriate for handling the emergency.

\(2\) Recognizing an uncontrollable emergency and taking action to
minimize harm to the public and personnel, including prompt notification
of appropriate local officials of the emergency and possible need for
evacuation of the public in the vicinity of the LNG plant.

\(3\) Coordinating with appropriate local officials in preparation of an
emergency evacuation plan, which sets forth the steps required to
protect the public in the event of an emergency, including catastrophic
failure of an LNG storage tank.

\(4\) Cooperating with appropriate local officials in evacuations and
emergencies requiring mutual assistance and keeping these officials
advised of:

\(i\) The LNG plant fire control equipment, its location, and quantity
of units located throughout the plant;

\(ii\) Potential hazards at the plant, including fires;

\(iii\) Communication and emergency control capabilities at the LNG
plant; and,

\(iv\) The status of each emergency.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980; as amended by Amdt. 193-18,
69 FR 11330, March 10, 2004\]

**§193.2511 Personnel safety.**

\(a\) Each operator shall provide any special protective clothing and
equipment necessary for the safety of personnel while they are
performing emergency response duties.

\(b\) All personnel who are normally on duty at a fixed location, such
as a building or yard, where they could be harmed by thermal radiation
from a burning pool of impounded liquid, must be provided a means of
protection at that location from the harmful effects of thermal
radiation or a means of escape.

\(c\) Each LNG plant must be equipped with suitable first-aid material,
the location of which is clearly marked and readily available to
personnel.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2513 Transfer procedures.**

\(a\) Each transfer of LNG or other hazardous fluid must be conducted in
accordance with one or more manuals of written procedures to provide for
safe transfers.

\(b\) The transfer procedures must include provisions for personnel to:

\(1\) Before transfer, verify that the transfer system is ready for use,
with connections and controls in proper positions, including if the
system could contain a combustible mixture, verifying that it has been
adequately purged in accordance with a procedure which meets the
requirements of AGA \"Purging Principles and Practice.\"

\(2\) Before transfer, verify that each receiving container or tank
vehicle does not contain any substance that would be incompatible with
the incoming fluid and that there is sufficient capacity available to
receive the amount of fluid to be transferred.

\(3\) Before transfer, verify the maximum filling volume of each
receiving container or tank vehicle to ensure that expansion of the
incoming fluid due to warming will not result in overfilling or
overpressure;

\(4\) When making bulk transfer of LNG into a partially filled
(excluding cooldown heel) container, determine any differences in
temperature or specific gravity between the LNG being transferred and
the LNG already in the container and, if necessary, provide a means to
prevent rollover due to stratification.

\(5\) Verify that the transfer operations are proceeding within design
conditions and that overpressure or overfilling does not occur by
monitoring applicable flow rates, liquid levels, and vapor returns.

\(6\) Manually terminate the flow before overfilling or overpressure
occurs; and,

\(7\) Deactivate cargo transfer systems in a safe manner by
depressurizing, venting, and disconnecting lines and conducting any
other appropriate operations.

\(c\) In addition to the requirements of paragraph (b) of this section,
the procedures for cargo transfer must be located at the transfer area
and include provisions for personnel to:

\(1\) Be in constant attendance during all cargo transfer operations;

\(2\) Prohibit the backing of tank trucks in the transfer area, except
when a person is positioned at the rear of the truck giving instructions
to the driver;

\(3\) Before transfer, verify that:

\(i\) Each tank car or tank truck complies with applicable regulations
governing its use;

\(ii\) All transfer hoses have been visually inspected for damage and
defects;

\(iii\) Each tank truck is properly immobilized with chock wheels, and
electrically grounded; and,

\(iv\) Each tank truck engine is shut off unless it is required for
transfer operations;

\(4\) Prevent a tank truck engine that is off during transfer operations
from being restarted until the transfer lines have been disconnected and
any released vapors have dissipated;

\(5\) Prevent loading LNG into a tank car or tank truck that is not in
exclusive LNG service or that does not contain a positive pressure if it
is in exclusive LNG service, until after the oxygen content in the tank
is tested and if it exceeds 2 percent by volume, purged in accordance
with a procedure that meets the requirements of AGA \"Purging Principles
and Practice\";

\(6\) Verify that all transfer lines have been disconnected and
equipment cleared before the tank car or tank truck is moved from the
transfer position; and,

\(7\) Verify that transfers into a pipeline system will not exceed the
pressure or temperature limits of the system.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2515 Investigations of failures.**

\(a\) Each operator shall investigate the cause of each explosion, fire,
or LNG spill or leak which results in:

\(1\) Death or injury requiring hospitalization; or

\(2\) Property damage exceeding \$10,000.

\(b\) As a result of the investigation, appropriate action must be taken
to minimize recurrence of the incident.

\(c\) If the Administrator or relevant state agency under the pipeline
safety laws (49 U.S.C. 60101 *et seq.*) investigates an incident, the
operator involved shall make available all relevant information and
provide reasonable assistance in conducting the investigation. Unless
necessary to restore or maintain service, or for safety, no component
involved in the incident may be moved from its location or otherwise
altered until the investigation is complete or the investigating agency
otherwise provides. Where components must be moved for operational or
safety reasons, they must not be removed from the plant site and must be
maintained intact to the extent practicable until the investigation is
complete or the investigating agency otherwise provides.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980 as amended by Amdt. 193-3A, 50
FR 4578, Amdt. 193-10, 61 FR 18512, Apr. 26, 1996\]

**§193.2517 Purging.**

When necessary for safety, components that could accumulate significant
amounts of combustible mixtures must be purged in accordance with a
procedure which meets the provisions of the AGA \"Purging Principles and
Practice\" after being taken out of service and before being returned to
service.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2519 Communication systems.**

\(a\) Each LNG plant must have a primary communication system that
provides for verbal communications between all operating personnel at
their work stations in the LNG plant.

\(b\) Each LNG plant in excess of 70,000 gallons (265,000 liters)
storage capacity must have an emergency communication system that
provides for verbal communications between all persons and locations
necessary for the orderly shutdown of operating equipment and the
operation of safety equipment in time of emergency. The emergency
communication system must be independent of and physically separated
from the primary communication system and the security communication
system under §193.2909.

\(c\) Each communication system required by this part must have an
auxiliary source of power, except sound-powered equipment.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980 as amended by Amdt. 193-16, 63
FR 37500, July 13, 1998\]

**§193.2521 Operating records.**

Each operator shall maintain a record of results of each inspection,
test and investigation required by this subpart. For each LNG facility
that is designed and constructed after March 31, 2000 the operator shall
also maintain related inspection, testing, and investigation records
that NFPA 59A (incorporated by reference, *see* §193.2013) requires.
Such records, whether required by this part or NFPA 59A, must be kept
for a period of not less than five years.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980 as amended by Amdt. 193-17, 65
FR 10950, March 1, 2000; Amdt. 193-18, 69 FR 11330, March 10, 2004\]

**Subpart G--Maintenance**

**§193.2601 Scope.**

This subpart prescribes requirements for maintaining components at LNG
plants.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2603 General.**

\(a\) Each component in service, including its support system, must be
maintained in a condition that is compatible with its operational or
safety purpose by repair, replacement, or other means.

\(b\) An operator may not place, return, or continue in service any
component which is not maintained in accordance with this subpart.

\(c\) Each component taken out of service must be identified in the
records kept under §193.2639.

\(d\) If a safety device is taken out of service for maintenance, the
component being served by the device must be taken out of service unless
the same safety function is provided by an alternate means.

\(e\) If the inadvertent operation of a component taken out of service
could cause a hazardous condition, that component must have a tag
attached to the controls bearing the words \"do not operate\" or words
of comparable meaning.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2605 Maintenance procedures.**

\(a\) Each operator shall determine and perform, consistent with
generally accepted engineering practice, the periodic inspections or
tests needed to meet the applicable requirements of this subpart and to
verify that components meet the maintenance standards prescribed by this
subpart.

\(b\) Each operator shall follow one or more manuals of written
procedures for the maintenance of each component, including any required
corrosion control. The procedure must include:

\(1\) The details of the inspections or tests determined under paragraph
(a) of this section and their frequency of performance; and

\(2\) A description of other actions necessary to maintain the LNG plant
in accordance with the requirements of this subpart.

\(c\) Each operator shall include in the manual required by paragraph
(b) of this section instructions enabling personnel who perform
operation and maintenance activities to recognize conditions that
potentially may be safety-related conditions that are subject to the
reporting requirements of §191.23 of this subchapter.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980, as amended by Amdt. 193-5, 53
FR 24942, July 1, 1988; Amdt. 193-5(1), 53 FR 26560, July 13, 1988;
Amdt. 193-18, 69 FR 11330, March 10, 2004\]

**§193.2607 Foreign material.**

\(a\) The presence of foreign material, contaminants, or ice shall be
avoided or controlled to maintain the operational safety of each
component.

\(b\) LNG plant grounds must be free from rubbish, debris, and other
material which present a fire hazard. Grass areas on the LNG plant
grounds must be maintained in a manner that does not present a fire
hazard.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2609 Support systems.**

Each support system or foundation of each component must be inspected
for any detrimental change that could impair support.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2611 Fire protection.**

\(a\) Maintenance activities on fire control equipment must be scheduled
so that a minimum of equipment is taken out of service at any one time
and is returned to service in a reasonable period of time.

\(b\) Access routes for movement of fire control equipment within each
LNG plant must be maintained to reasonably provide for use in all
weather conditions.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2613 Auxiliary power sources.**

Each auxiliary power source must be tested monthly to check its
operational capability and tested annually for capacity. The capacity
test must take into account the power needed to start up and
simultaneously operate equipment that would have to be served by that
power source in an emergency.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2615 Isolating and purging.**

\(a\) Before personnel begin maintenance activities on components
handling flammable fluids which are isolated for maintenance, the
component must be purged in accordance with a procedure which meets the
requirements of AGA \"Purging Principles and Practice,\" unless the
maintenance procedures under §193.2605 provide that the activity can be
safely performed without purging.

\(b\) If the component or maintenance activity provides an ignition
source, a technique in addition to isolation valves (such as removing
spool pieces or valves and blank flanging the piping, or double block
and bleed valving) must be used to ensure that the work area is free of
flammable fluids

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2617 Repairs.**

\(a\) Repair work on components must be performed and tested in a manner
which:

\(1\) As far as practicable, complies with the applicable requirements
of Subpart D of this part; and

\(2\) Assures the integrity and operational safety of the component
being repaired.

\(b\) For repairs made while a component is operating, each operator
shall include in the maintenance procedures under §193.2605 appropriate
precautions to maintain the safety of personnel and property during
repair activities.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2619 Control systems.**

\(a\) Each control system must be properly adjusted to operate within
design limits.

\(b\) If a control system is out of service for 30 days or more, it must
be inspected and tested for operational capability before returning it
to service.

\(c\) Control systems in service, but not normally in operation, such as
relief valves and automatic shutdown devices, and control systems for
internal shutoff valves for bottom penetration tanks must be inspected
and tested once each calender year, not exceeding 15 months, with the
following exceptions:

\(1\) Control systems used seasonally, such as for liquefaction or
vaporization, must be inspected and tested before use each season.

\(2\) Control systems that are intended for fire protection must be
inspected and tested at regular intervals not to exceed 6 months.

\(d\) Control systems that are normally in operation, such as required
by a base load system, must be inspected and tested once each calendar
year but with intervals not exceeding 15 months.

\(e\) Relief valves must be inspected and tested for verification of the
valve seat lifting pressure and reseating.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980 as amended by Amdt. 193-17, 65
FR 10950, March 1, 2000\]

**§193.2621 Testing transfer hoses.**

Hoses used in LNG or flammable refrigerant transfer systems must be:

\(a\) Tested once each calendar year, but with intervals not exceeding
15 months, to the maximum pump pressure or relief valve setting; and

\(b\) Visually inspected for damage or defects before each use.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2623 Inspecting LNG storage tanks.**

Each LNG storage tank must be inspected or tested to verify that each of
the following conditions does not impair the structural integrity or
safety of the tank:

\(a\) Foundation and tank movement during normal operation and after a
major meteorological or geophysical disturbance.

\(b\) Inner tank leakage.

\(c\) Effectiveness of insulation.

\(d\) Frost heave.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980, as amended by Amdt.
192-34(1), 47 FR 32720, July 29, 1982\]

**§193.2625 Corrosion protection.**

\(a\) Each operator shall determine which metallic components could,
unless corrosion is controlled, have their integrity or reliability
adversely affected by external, internal, or atmospheric corrosion
during their intended service life.

\(b\) Components whose integrity or reliability could be adversely
affected by corrosion must be either--

\(1\) Protected from corrosion in accordance with §§193.2627 through
193.2635, as applicable; or

\(2\) Inspected and replaced under a program of scheduled maintenance in
accordance with procedures established under §193.2605.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2627 Atmospheric corrosion control.**

Each exposed component that is subject to atmospheric corrosive attack
must be protected from atmospheric corrosion by:

\(a\) Material that has been designed and selected to resist the
corrosive atmosphere involved; or

\(b\) Suitable coating or jacketing.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2629 External corrosion**

**control; buried or submerged**

**components.**

\(a\) Each buried or submerged component that is subject to external
corrosive attack must be protected from external corrosion by:

\(1\) Material that has been designed and selected to resist the
corrosive environment involved; or

\(2\) The following means:

\(i\) An external protective coating designed and installed to prevent
corrosion attack and to meet the requirements of §192.461 of this
chapter; and

\(ii\) A cathodic protection system designed to protect components in
their entirety in accordance with the requirements of §192.463 of this
chapter and placed in operation before October 23, 1981, or within 1
year after the component is constructed or installed, whichever is
later.

\(b\) Where cathodic protection is applied, components that are
electrically interconnected must be protected as a unit.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980, as amended by Amdt.
192-34(1), 47 FR 32720, July 29, 1982\]

**§193.2631 Internal corrosion control.**

Each component that is subject to internal corrosive attack must be
protected from internal corrosion by:

\(a\) Material that has been designed and selected to resist the
corrosive fluid involved; or

\(b\) Suitable coating, inhibitor, or other means.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2633 Interference currents.**

\(a\) Each component that is subject to electrical current interference
must be protected by a continuing program to minimize the detrimental
effects of currents.

\(b\) Each cathodic protection system must be designed and installed so
as to minimize any adverse effects it might cause to adjacent metal
components.

\(c\) Each impressed current power source must be installed and
maintained to prevent adverse interference with communications and
control systems.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2635 Monitoring corrosion control.**

Corrosion protection provided as required by this subpart must be
periodically monitored to give early recognition of ineffective
corrosion protection, including the following, as applicable:

\(a\) Each buried or submerged component under cathodic protection must
be tested at least once each calendar year, but with intervals not
exceeding 15 months, to determine whether the cathodic protection meets
the requirements of §192.463 of this chapter.

\(b\) Each cathodic protection rectifier or other impressed current
power source must be inspected at least six times each calendar year,
but with intervals not exceeding 2½ months, to ensure that it is
operating properly.

\(c\) Each reverse current switch, each diode, and each interference
bond whose failure would jeopardize component protection must be
electrically checked for proper performance at least six times each
calendar year, but with intervals not exceeding 2½ months. Each other
interference bond must be checked at least once each calendar year, but
with intervals not exceeding 15 months.

\(d\) Each component that is protected from atmospheric corrosion must
be inspected at intervals not exceeding 3 years.

\(e\) If a component is protected from internal corrosion, monitoring
devices designed to detect internal corrosion, such as coupons or
probes, must be located where corrosion is most likely to occur.
However, monitoring is not required for corrosion resistant materials if
the operator can demonstrate that the component will not be adversely
affected by internal corrosion during its service life. Internal
corrosion control monitoring devices must be checked at least two times
each calendar year, but with intervals not exceeding 7½ months.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2637 Remedial measures.**

Prompt corrective or remedial action must be taken whenever an operator
learns by inspection or otherwise that atmospheric, external, or
internal corrosion is not controlled as required by this subpart.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2639 Maintenance records.**

\(a\) Each operator shall keep a record at each LNG plant of the date
and type of each maintenance activity performed on each component to
meet the requirements of this part. For each LNG facility that is
designed and constructed after March 31, 2000 the operator shall also
maintain related periodic inspection and testing records that NFPA 59A
(incorporated by reference, *see* §193.2013) requires. Maintenance
records, whether required by this part or NFPA 59A, must be kept for a
period of not less than five years. (b) Each operator shall maintain
records or maps to show the location of cathodically protected
components, neighboring structures bonded to the cathodic protection
system, and corrosion protection equipment.

\(c\) Each of the following records must be retained for as long as the
LNG facility remains in service:

\(1\) Each record or map required by paragraph (b) of this section.

\(2\) Records of each test, survey, or inspection required by this
subpart in sufficient detail to demonstrate the adequacy of corrosion
control measures.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980 as amended by Amdt. 193-17, 65
FR 10950, March 1, 2000; Amdt. 193-18, 69 FR 11330, March 10, 2004\]

**Subpart HPersonnel Qualifications and Training**

**§193.2701 Scope.**

This subpart prescribes requirements for personnel qualifications and
training.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980\]

**§193.2703 Design and fabrication.**

For the design and fabrication of components, each operator shall use--

\(a\) With respect to design, persons who have demonstrated competence
by training or experience in the design of comparable components.

\(b\) With respect to fabrication, persons who have demonstrated
competence by training or experience in the fabrication of comparable
components.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980\]

**§193.2705 Construction, installation, inspection, and testing.**

\(a\) Supervisors and other personnel utilized for construction,
installation, inspection, or testing must have demonstrated their
capability to perform satisfactorily the assigned function by
appropriate training in the methods and equipment to be used or related
experience and accomplishments.

\(b\) Each operator must periodically determine whether inspectors
performing construction, installation, and testing duties required by
this part are satisfactorily performing their assigned function.

\[Part 193 - Org., 45 FR 9184, Feb 11, 1980 as amended by Amdt. 193-18,
69 FR 11330, March 10, 2004\]

**§193.2707 Operations and maintenance.**

\(a\) Each operator shall utilize for operation or maintenance of
components only those personnel who have demonstrated their capability
to perform their assigned functions by--

\(1\) Successful completion of the training required by §§193.2713 and
193.2717;

\(2\) Experience related to the assigned operation or maintenance
function; and,

\(3\) Acceptable performance on a proficiency test relevant to the
assigned function.

\(b\) A person who does not meet the requirements of paragraph (a) of
this section may operate or maintain a component when accompanied and
directed by an individual who meets the requirements.

\(c\) Corrosion control procedures under §193.2605(b), including those
for the design, installation, operation, and maintenance of cathodic
protection systems, must be carried out by, or under the direction of, a
person qualified by experience and training in corrosion control
technology.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2709 Security.**

Personnel having security duties must be qualified to perform their
assigned duties by successful completion of the training required under
§193.2715.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2711 Personnel health.**

Each operator shall follow a written plan to verify that personnel
assigned operating, maintenance, security, or fire protection duties at
the LNG plant do not have any physical condition that would impair
performance of their assigned duties. The plan must be designed to
detect both readily observable disorders, such as physical handicaps or
injury, and conditions requiring professional examination for discovery.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2713 Training; operations and maintenance.**

\(a\) Each operator shall provide and implement a written plan of
initial training to instruct--

\(1\) All permanent maintenance, operating, and supervisory personnel--

\(i\) About the characteristics and hazards of LNG and other flammable
fluids used or handled at the facility, including, with regard to LNG,
low temperatures, flammability of mixtures with air, odorless vapor,
boiloff characteristics, and reaction to water and water spray;

\(ii\) About the potential hazards involved in operating and maintenance
activities; and,

\(iii\) To carry out aspects of the operating and maintenance procedures
under §§193.2503 and 193.2605 that relate to their assigned functions;
and

\(2\) All personnel--

\(i\) To carry out the emergency procedures under §193.2509 that relate
to their assigned functions; and

\(ii\) To give first-aid; and,

\(3\) All operating and appropriate supervisory personnel--

\(i\) To understand detailed instructions on the facility operations,
including controls, functions, and operating procedures; and

\(ii\) To understand the LNG transfer procedures provided under
§193.2513.

\(b\) A written plan of continuing instruction must be conducted at
intervals of not more than 2 years to keep all personnel current on the
knowledge and skills they gained in the program of initial instruction.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2715 Training; security.**

\(a\) Personnel responsible for security at an LNG plant must be trained
in accordance with a written plan of initial instruction to:

\(1\) Recognize breaches of security;

\(2\) Carry out the security procedures under §193.2903 that relate to
their assigned duties;

\(3\) Be familiar with basic plant operations and emergency procedures,
as necessary to effectively perform their assigned duties; and,

\(4\) Recognize conditions where security assistance is needed.

\(b\) A written plan of continuing instruction must be conducted at
intervals of not more than 2 years to keep all personnel having security
duties current on the knowledge and skills they gained in the program of
initial instruction.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2717 Training; fire protection.**

\(a\) All personnel involved in maintenance and operations of an LNG
plant, including their immediate supervisors, must be trained according
to a written plan of initial instruction, including plant fire drills,
to:

\(1\) Know the potential causes and areas of fire;

\(2\) Know the types, sizes, and predictable consequences of fire; and

\(3\) Know and be able to perform their assigned fire control duties
according to the procedures established under §193.2509 and by proper
use of equipment provided under §193.2801.

\(b\) A written plan of continuing instruction, including plant fire
drills, must be conducted at intervals of not more than 2 years to keep
personnel current on the knowledge and skills they gained in the
instruction under paragraph (a) of this section.

\(c\) Plant fire drills must provide personnel hands-on experience in
carrying out their duties under the fire emergency procedures required
by §193.2509.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980; as amended by Amdt. 193-18,
69 FR 11330, March 10, 2004\]

**§193.2719 Training; records.**

\(a\) Each operator shall maintain a system of records which--

\(1\) Provide evidence that the training programs required by this
subpart have been implemented; and

\(2\) Provide evidence that personnel have undergone and satisfactorily
completed the required training programs.

\(b\) Records must be maintained for 1 year after personnel are no
longer assigned duties at the LNG plant.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**Subpart IFire Protection**

**§193.2801 Scope.**

Each operator must provide and maintain fire protection at LNG plants
according to sections 9.1 through 9.7 and section 9.9 of NFPA 59A
(incorporated by reference, *see* §193.2013). However, LNG plants
existing on March 31, 2000, need not comply with provisions on emergency
shutdown systems, water delivery systems, detection systems, and
personnel qualification and training until September 12, 2005.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980 as amended by Amdt. 193-4, 52
FR 674, Jan. 8, 1987, Amdt. 193-17, 65 FR 10950, March 1, 2000; Amdt.
193-18, 69 FR 11330, March 10, 2004\]

**Subpart JSecurity**

**§193.2901 Scope.**

This subpart prescribes requirements for security at LNG plants.
However, the requirements do not apply to existing LNG plants that do
not contain LNG.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980 as amended by Amdt. 193-4, 52
FR 674, Jan. 8, 1987\]

**§193.2903 Security procedures.**

Each operator shall prepare and follow one or more manuals of written
procedures to provide security for each LNG plant. The procedures must
be available at the plant in accordance with §193.2017 and include at
least:

\(a\) A description and schedule of security inspections and patrols
performed in accordance with §193.2913;

\(b\) A list of security personnel positions or responsibilities
utilized at the LNG plant;

\(c\) A brief description of the duties associated with each security
personnel position or responsibility;

\(d\) Instructions for actions to be taken, including notification of
other appropriate plant personnel and law enforcement officials, when
there is any indication of an actual or attempted breach of security;

\(e\) Methods for determining which persons are allowed access to the
LNG plant;

\(f\) Positive identification of all persons entering the plant and on
the plant, including methods at least as effective as picture badges;
and,

\(g\) Liaison with local law enforcement officials to keep them informed
about current security procedures under this section.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2905 Protective enclosures.**

\(a\) The following facilities must be surrounded by a protective
enclosure:

\(1\) Storage tanks;

\(2\) Impounding systems;

\(3\) Vapor barriers;

\(4\) Cargo transfer systems;

\(5\) Process, liquefaction, and vaporization equipment;

\(6\) Control rooms and stations;

\(7\) Control systems;

\(8\) Fire control equipment;

\(9\) Security communications systems; and,

\(10\) Alternative power sources.

The protective enclosure may be one or more separate enclosures
surrounding a single facility or multiple facilities.

\(b\) Ground elevations outside a protective enclosure must be graded in
a manner that does not impair the effectiveness of the enclosure.

\(c\) Protective enclosures may not be located near features outside of
the facility, such as trees, poles, or buildings, which could be used to
breach the security.

\(d\) At least two accesses must be provided in each protective
enclosure and be located to minimize the escape distance in the event of
emergency.

\(e\) Each access must be locked unless it is continuously guarded.
During normal operations, an access may be unlocked only by persons
designated in writing by the operator. During an emergency, a means must
be readily available to all facility personnel within the protective
enclosure to open each access.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2907 Protective enclosure construction.**

\(a\) Each protective enclosure must have sufficient strength and
configuration to obstruct unauthorized access to the facilities
enclosed.

\(b\) Openings in or under protective enclosures must be secured by
grates, doors or covers of construction and fastening of sufficient
strength such that the integrity of the protective enclosure is not
reduced by any opening.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980 as amended by Amdt. 193-12, 61
FR 27789, June 3, 1996; Amdt. 193-12A, 61 FR 45905, Aug. 30, 1996\]

**§193.2909 Security communications.**

A means must be provided for:

\(a\) Prompt communications between personnel having supervisory
security duties and law enforcement officials; and

\(b\) Direct communications between all on-duty personnel having
security duties and all control rooms and control stations.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2911 Security lighting.**

Where security warning systems are not provided for security monitoring
under §193.2913, the area around the facilities listed under
§193.2905(a) and each protective enclosure must be illuminated with a
minimum in service lighting intensity of not less than 2.2 lux (0.2
ft^c^) between sunset and sunrise.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2913 Security monitoring.**

Each protective enclosure and the area around each facility listed in
§193.2905(a) must be monitored for the presence of unauthorized persons.
Monitoring must be by visual observation in accordance with the schedule
in the security procedures under §193.2903(a) or by security warning
systems that continuously transmit data to an attended location. At an
LNG plant with less than 40,000 m^3^ (250,000 bbl) of storage capacity,
only the protective enclosure must be monitored.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2915 Alternative power sources.**

An alternative source of power that meets the requirements of §193.2445
must be provided for security lighting and security monitoring and
warning systems required under §§193.2911 and 193.2913.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980\]

**§193.2917 Warning signs.**

\(a\) Warning signs must be conspicuously placed along each protective
enclosure at intervals so that at least one sign is recognizable at
night from a distance of 30 m (100 ft.) from any way that could
reasonably be used to approach the enclosure.

\(b\) Signs must be marked with at least the following on a background
of sharply contrasting color: The words \"NO TRESPASSING\", or words of
comparable meaning.

\[Amdt. 193-2, 45 FR 70390, Oct. 23, 1980, as amended by Amdt.
192-34(1), 47 FR 32720, July 29, 1982\]