Ch. 31F Marine Oil Terminals — 2025 California Building Code

(Matrix Adoption Tables are nonregulatory, intended only as an aid to the code user. See Chapter 1 for state agency authority and building applications.)

The state agency does not adopt sections identified with the following symbol: The Office of the State Fire Marshal’s adoption of this chapter or individual sections is applicable to structures regulated by other state agencies pursuant to Section 1.11.

31F [SLC] MARINE OIL TERMINALS

DIVISION I

The extreme thickness of insulation on cryogenic piping shall be taken into consideration during piping design._ 2. All piping materials, including gaskets and thread compounds, shall be selected appropriate to the range of temperatures to which subjected. Piping that may be exposed to the low temperature of LNG or to the heat of an ignited spill, during an emer- gency where such exposure could result in a failure of the piping, shall comply with at least one of the following: (a) Made of material(s) that can withstand both the normal operating temperature and extreme temperature to which the piping may be subjected during the emergency

(b) Protected by insulation or other means to delay failure due to extreme temperatures until corrective action can be taken by the operator. (c) Capable of being isolated and having the flow stopped where piping is exposed only to the heat of an ignited spill during the emergency 3. LNG pipelines shall be designed for cool-down with liquid nitrogen where the use of LNG is not possible. 4. All LNG drains should be located within a containment area or piped to a collection system or containment area. 5. LNG lines shall be analyzed for a start-up case where the top of the pipe is 90 degrees F warmer than the bottom of the pipe. The upward bowing of the pipe shall be limited to 1.25 inches. 6. Pipe supports, including any insulation systems used to support pipe whose stability is essential, shall be resistant to or protected against fire exposure, escaping cold liquid, or both if they are subject to such exposure. 7. Pipe supports for cold lines shall be designed to minimize excessive heat transfer, which can result in piping failure by ice formations or embrittlement of supporting steel. If icing up of piping and components is unavoidable, the weight of the accu- mulated ice shall be considered during piping and support design. 8. Valves shall comply with ASME B31.5 [12.5]. 9. Cryogenic valves in liquid cryogenic service shall not be installed in vertical lines. Valves in liquid cryogenic service shall be installed in horizontal lines with the stem in the vertical position or at least 45 degrees vertically from the horizontal centerline of the pipe. 10. All cryogenic valves (except butterfly valves, check valves and globe valves) shall have a body cavity relief to the “safe” side of the valve. All cryogenic valves with a body cavity relief shall be marked on the exterior of the body with a letter “V” and an arrow pointing to the direction of the venting side. 11. Thermal relief valves shall be installed to protect the equipment and piping from over pressuring as a result of ambient heat input to blocked in LNG or other light hydrocarbon liquids. 12. Cryogenic subsea pipeline designs shall be qualified by a certifying agency, acceptable to the Division, in a qualification program that demonstrates that the system has been designed, fabricated and can function as intended with safeguards provided as determined to be necessary.

1. The CEA analysis shall be used to recommend acceptable cryogenic exposure durations for Safety Critical Components to produce CEA drawings. 2. ESD system components, which are exposed to cryogenic effects, shall be evaluated to confirm that the actuators will not be impaired by the potential exposures, thereby preventing the components from failing to a safe position. 3. Critical structural supports and equipment within the cryogenically exposed areas shall be provided with cryogenic insulation. The cryogenic insulation and passive fire protection shall be designed for sufficient incident duration. 4. For marine loading arms in LNG service, ice formation on non-insolated arms and hoses must be taken into account. Mecha- nisms for venting, apex venting, purging and cool down of the marine loading arms shall be identified on the P&IDs. 5. Areas beneath marine arms shall have restricted access during and after product transfer, until there is no longer danger of falling ice.

[12.1] Oil Companies International Marine Forum (OCIMF), 2008, “Mooring Equipment Guidelines (MEG3),” 3rd ed., London, England.

[12.2] American Petroleum Institute (API), 2001 (Reaffirmed 2007), API Recommended Practice 14C (API RP 14C), “Recommended Practice for Analysis, Design, Installation, and Testing of Basic Surface Safety Systems for Offshore Production Platforms,” 7th ed., Washington, D.C.

[12.3] National Fire Protection Association (NFPA), 2012, NFPA 59A, “Standard for the Production, Storage, and Handling of Lique- fied Natural Gas (LNG),” 2013 ed., Quincy, MA.

[12.4] American Society of Mechanical Engineers (ASME), 2015, ASME B31.3-2014 (ASME B31.3), “Process Piping,” New York.

[12.5] American Society of Mechanical Engineers (ASME), 2013, ASME B31.5-2013 (ASME B31.5), “Refrigeration Piping and Heat Transfer Components,” New York.

Authority: Sections 8750 through 8760, Public Resources Code.

Reference: Sections 8750, 8751, 8755 and 8757, Public Resources Code.

CHAPTER 32 – ENCROACHMENTS INTO THE PUBLIC RIGHT-OF-WAY

(Matrix Adoption Tables are nonregulatory, intended only as an aid to the code user. See Chapter 1 for state agency authority and building applications.)

The state agency does not adopt sections identified with the following symbol: The Office of the State Fire Marshal’s adoption of this chapter or individual sections is applicable to structures regulated by other state agencies pursuant to Section 1.11.