(2) Identification and evaluation of all historically reported earthquakes which could affect the determination under this section of the most critical ground motion or differential displacement at the site when correlated with particular faults, tectonic structures, and tectonic provinces, as applicable; and
(3) Identification and evaluation of the hydrologic regime and the potential of liquefaction-induced soil failures.
(d) The most critical ground motion must be determined in accordance with paragraph (e) of this section either:
(1) Probabilistically, when the available earthquake data are sufficient to show that the yearly probability of exceedance of most critical ground motion is 10 -4 or less; or
(2) Deterministically, when the available earthquake data are insufficient to provide probabilistic estimates, with the objective of determining a most critical ground motion with a yearly probability of exceedance of 10-4 or less.
(e) The determination of most critical ground motion, considering local and regional seismological conditions, must be made by using the following:
(1) A regionally appropriate attenuation relationship, assuming that earthquakes occur at a location on a fault, tectonic structure, or tectonic province, as applicable, which would cause the most critical seismic movement at the site, except that where epicenters of historically reported earthquakes cannot be reasonably related to known faults or tectonic structures, but are recognized as being within a specific tectonic province which is within 100 miles of the site, assume that those earthquakes occur within their respective provinces at a source closest to the site.
(2) A horizontal design response spectrum determined from the mean plus one standard deviation of a free-field horizontal elastic response spectra whose spectral amplitudes are consistent with values expected for the most critical ground motion.
(3) A vertical design response spectrum that is either two-thirds of the amplitude of the horizontal design response spectrum at all frequencies or equal to the horizontal design response spectrum where the site is located within 10 miles of the earthquake source.
(f) An LNG storage tank or its impounding system may not be located at a site where an investigation under paragraph (c) of this section shows that any of the following conditions exists unless the Administrator grants an approval for the site:
(1) The estimated design horizontal acceleration exceeds 0.8g at the tank or dike foundation.
(2) The specific local geologic and seismic data base is sufficient to predict future differential surface displacement beneath the tank and dike area, but displacement not exceeding 30 inches cannot be assured with a high level of confidence.
(3) The specific local geologic and seismic data base is not sufficient to predict future differential surface displacement beneath the tank and dike area, and the estimated cumulative displacement of a Quaternary fault within one mile of the tank foundation exceeds 60 inches.
(4) The potential for soil liquefaction cannot be accommodated by design and construction in accordance with paragraph (b)(1) of this section.
(g) An application for approval of a site under paragraph (f) of this section must provide at least the following:
(1) A detailed analysis and evaluation of the geologic and seismic characteristics of the site based on the geotechnical investigation performed under paragraph (c) of this section, with emphasis on prediction of near-field seismic response.
(2) The design plans and structural analysis for the tank, its impounding system, and related foundations, with a report demonstrating that the design requirements of this section are satisfied, including any test results or other documentation as appropriate.
(3) A description of safety-related features of the site or designs, in addition to those required by this part, if applicable, that would mitigate the potential effects of a catastrophic spill (e.g., remoteness or topographic features of the site, additional exclusion distances, or multiple barriers for containing or impounding LNG).
(h) Each container which does not have a structurally liquid-tight cover must have sufficient freeboard with an appropriate configuration to prevent the escape of liquid due to sloshing, wave action, and vertical liquid displacement caused by seismic action.
[45 FR 9203, Feb. 11, 1980, as amended by Amdt. 193-1, 45 FR 57419, Aug. 28, 1980]
193.2063 Flooding.
(a) Each operator shall determine the effects of flooding on an LNG facility site based on the worst occurrence in a 100-year period. The determination must take into account:
(1) Volume and velocity of the floodwater;
(2) Tsunamis (local, regional, and distant);
(3) Potential failure of dams;
(4) Predictable land developments which would affect runoff accumulation of water; and
(5) Tidal action.
(b) The effect of flooding determined under paragraph (a) of this section must be accommodated by location or design and construction, as applicable, to reasonably assure:
(1) The structural or functional integrity of LNG facilities; and
(2) Access from outside the LNG facility and movement of personnel and equipment about the LNG facility site for the control of fire and other emergencies.
193.2065 Soil characteristics.
(a) Soil investigations including borings and other appropriate tests must be made at the site of each LNG facility to determine bearing capacity, settlement characteristics, potential for erosion, and other soil characteristics applicable to the integrity of the facility.
(b) The naturally occurring or designed soil characteristics at each LNG facility site must provide load bearing capacities, using appropriate safety factors, which can support the following loads without excessive lateral or vertical movement that causes a loss of the functional or structural integrity of the facility involved:
(1) Static loading caused by the facility and its contents and any hydrostatic testing of the facility; and
(2) Dynamic loading caused by movement of contents of the facility during normal operation, including flow, sloshing, and rollover.
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 ASCE 7-88.
(2) For all other LNG facilities --
(i) An assumed sustained wind velocity of not less than 200 miles per hour, unless the Administrator, RSPA 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.
[45 FR 9203, Feb. 11, 1980, as amended by Amdt. 193-1, 45 FR 57419, Aug. 28, 1980; 58 FR 14522, March 18, 1993]
193.2069 Other severe weather and natural conditions.
(a) In addition to the requirements of §
193.2061, 193.2063, 193.2065, and 193.2067, each operator shall determine from historical records and engineering studies the worst effect of other weather and natural conditions which may predictably occur at an LNG facility site.
(b) The facility must be located and designed so that such severe conditions cannot reasonably be expected to result in an emergency involving the factors listed in §
193.2063(b).
193.2071 Adjacent activities.
(a) Each operator shall determine that present and reasonably foreseeable activities adjacent to an LNG facility site that could adversely affect the operation of the LNG facility or the safety of persons or offsite property, if damage to the facility occurs.
(b) An LNG facility must not be located where present or projected offsite activities would be reasonably expected to:
(1) Adversely affect the operation of any of its safety control systems;
(2) Cause failure of the facility; or
(3) Cause the facility not to meet the requirements of this part.
193.2073 Separation of facilities.
Each LNG facility site must be large enough to provide for minimum separations between facilities and between facilities and the site boundary to:
(a) Permit movement of personnel, maintenance equipment, and emergency equipment around the facility; and
(b) Comply with distances specified in sections 2-2.4 through 2-2.7 of ANSI/NFPA 59A.
[58 FR 14522, March 18, 1993]
RESEARCH AND SPECIAL PROGRAMS
ADMINISTRATION, DOT
SUBPART D -- CONSTRUCTION
193.2301 Scope.
This subpart prescribes requirements for the construction or installation of components.
193.2303 Construction acceptance.
No person may place in service any component until it passes all applicable inspections and tests prescribed by this subpart.
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.
[Amdt. 193-2, 45 FR 70404, Oct. 23, 1980]
193.2305 Procedures.
(a) In performing construction, installation, inspection, or testing, an operator must follow written specifications, procedures, and drawings, as appropriate, that are consistent with this part, taking into account relevant mechanical, chemical, and thermal properties, component functions, and environmental effects that are involved.
(b) All procedures, including any field revisions, must be substantiated by testing or experience to produce a component that is reliable and complies with the design and installation requirements of this part.
193.2307 Inspection.
(a) All construction, installation, and testing activities must be inspected as frequently as necessary in accordance with a written plan to assure that --
(1) Activities are in compliance with all applicable requirements of this subpart; and
(2) Components comply with the applicable material, design, fabrication, installation, and construction requirements of this part.
(b) In addition to the requirements of paragraph (a) of this section, the construction of concrete storage tanks must be inspected in accordance with ACI 311.4R-88 or ACI 311.5R-88.
(c) Each operator shall have a quality assurance inspection program to verify that components comply with their design specifications and drawings, including any field design changes, before they are placed in service.
[58 FR 14522, March 18, 1993]
193.2309 Inspection and testing methods
Except as otherwise provided by this subpart, each operator shall determine, commensurate with the hazard that would result from failure of the component concerned, the scope and nature of --
