(a) Fixed sensors must have audio and visual alarms in the control room and audio alarms nearby.

(b) Fixed sensors that continuously monitor for LNG vapors must—

(1) Be in each enclosed area where vapor or gas may accumulate; and

(2) Meet Section 16.4 of NFPA 59A (incorporated by reference, see § 127.003).

(c) Fixed sensors that continuously monitor for flame, heat, or products of combustion must—

(1) Be in each enclosed or covered Class I, Division 1, hazardous location defined in Section 500.5(B)(1) of NFPA 70 (incorporated by reference, see § 127.003) and each area in which flammable or combustible material is stored; and

(2) Meet Section 16.4 of NFPA 59A (incorporated by reference, see § 127.003).

The marine transfer area for LNG must have at least two portable gas detectors capable of measuring 0-100% of the lower flammable limit of methane.

Each transfer system must have an emergency shutdown system that—

(a) Can be activated manually; and

(b) Is activated automatically when the fixed sensors under § 127.201(b) measure LNG concentrations exceeding 40% of the lower flammable limit.

(a) The marine transfer area for LNG must have a rotating or flashing amber light with a minimum effective flash intensity, in the horizontal plane, of 5000 candelas. At least 50% of the required effective flash intensity must be maintained in all directions from 1.0 degree above to 1.0 degree below the horizontal plane.

(b) The marine transfer area for LNG must have a siren with a minimum 1/3-octave band sound pressure level at l meter of 125 decibels referenced to 0.0002 microbars. The siren must be located so that the sound signal produced is audible over 360 degrees in a horizontal plane.

(c) Each light and siren must be located so that the warning alarm is not obstructed for a distance of 1.6 km (1 mile) in all directions.

The marine transfer area for LNG must meet the following criteria in NFPA 59A (incorporated by reference, see § 127.003):

(a) Chapter 5, Section 5.3.1.7;

(b) Chapter 6, Section 6.7;

(c) Chapter 10;

(d) Chapter 11, except Sections 11.9, and 11.10;

(e) Chapter 12;

(f) Chapter 15, except Sections 15.4 and 15.6; and

(g) Annex B.

(a) If the waterfront facility handling LNG is in a region subject to earthquakes, the piers and wharves must be designed to resist earthquake forces.

(b) Substructures, except moorings and breasting dolphins, that support or are within 5 meters (16.4 feet) of any pipe or equipment containing LNG, or are within 15 meters (49.2 feet) of a loading flange, must—

(1) Be made of concrete or steel; and

(2) Have a fire endurance rating of not less than two hours.

(c) LNG or LPG storage tanks must have the minimum volume necessary for—

(1) Surge protection;

(2) Pump suction supply; or

(3) Other process needs.

(a) LNG impounding spaces must be located so that the heat flux from a fire over the impounding spaces does not cause structural damage to an LNG vessel moored or berthed at the waterfront facility handling LNG.

(b) Each LNG loading flange must be located at least 300 meters (984.3 feet) from the following which are primarily intended for the use of the general public or railways:

(1) Each bridge crossing a navigable waterway.

(2) Each entrance to any tunnel under a navigable waterway.

(a) The electrical power system must have a power source and a separate emergency power source, so that failure of one source does not affect the capability of the other source. The system must meet NFPA 70 (incorporated by reference, see § 127.003).

(b) The emergency power source must provide enough power for the operation of the—

(1) Emergency shutdown system;

(2) Communications equipment;

(3) Firefighting equipment; and

(4) Emergency lighting.

(c) If an auxiliary generator is used as an emergency power source, it must meet Section 700.12 of NFPA 70 (incorporated by reference, see § 127.003).

(a) The marine transfer area for LNG must have a lighting system and separate emergency lighting.

(b) All outdoor lighting must be located or shielded so that it is not confused with any aids to navigation and does not interfere with navigation on the adjacent waterways.

(c) The lighting system must provide an average illumination on a horizontal plane one meter (3.3 feet) above the deck that is—

(1) 54 lux (five foot-candles) at any loading flange; and

(2) 11 lux (one foot-candle) at each work area.

(d) The emergency lighting must provide lighting for the operation of the—

(1) Emergency shutdown system;

(2) Communications equipment; and

(3) Firefighting equipment.

(a) The marine transfer area for LNG must have a ship-to-shore communication system and a separate emergency ship-to-shore communication system.

(b) Each ship-to-shore communication system must be a dedicated system that allows voice communication between the person in charge of transfer operations on the vessel, the person in charge of shoreside transfer operations, and personnel in the control room.

(a) The marine transfer area for LNG must have warning signs that—

(1) Meet paragraph (b) of this section;

(2) Can be seen from the shore and the water; and

(3) Have the following text:

(b) Each letter in the words on the sign must be—

(1) Block style;

(2) Black on a white background; and

(3) 7.6 centimeters (3 inches) high.

(a) No person may serve, and the operator of the waterfront facility handling LNG may not use the services of any person, as a person in charge of shoreside transfer operations, unless that person—

(1) Has at least 48 hours of LNG transfer experience;

(2) Knows the hazards of LNG;

(3) Knows the rules of this subpart; and

(4) Knows the procedures in the examined Operations Manual and the examined Emergency Manual.

(b) Before a person in charge of shoreside transfer operations supervises a transfer, the operator must certify in writing that the criteria in paragraph (a) of this section are met. The operator must maintain a copy of each current certification available for inspection at the waterfront facility handling LNG.

If an order to suspend is given to the operator or owner of the waterfront facility handling LNG, no LNG transfer operations may be conducted at the facility until the order is withdrawn by the COTP.

Each Operations Manual must contain—

(a) A description of the transfer system including mooring areas, transfer connections, control rooms, and diagrams of the piping and electrical systems;

(b) The duties of each person assigned for transfer operations;

(c) The maximum relief valve setting or maximum allowable working pressure of the transfer system;

(d) The facility telephone numbers of facility supervisors, persons in charge of shoreside transfer operations, personnel on watch in the marine transfer area for LNG, and security personnel;

(e) A description of the security systems for the marine transfer area for LNG;

(f) The procedures for—

(1) Transfer operations including gauging, cool down, pumping, venting, and shutdown;

(2) Transfer operations start-up and shutdown;

(3) Security violations; and

(4) The communications systems; and

(g) A description of the training programs established under § 127.503.

Each Emergency Manual must contain—

(a) LNG release response procedures, including contacting local response organizations;

(b) Emergency shutdown procedures;

(c) A description of the fire equipment and systems and their operating procedures;

(d) A description of the emergency lighting and emergency power systems;

(e) The telephone numbers of local Coast Guard units, hospitals, fire departments, police departments, and other emergency response organizations;

(f) If the waterfront facility handling LNG has personnel shelters, the location of and provisions in each shelter;

(g) First aid procedures and if there are first aid stations, the locations of each station; and

(h) Emergency procedures for mooring and unmooring a vessel.

The operator must ensure that—

(a) LNG transfer operations are not conducted unless the person in charge of transfer for the waterfront facility handling LNG has in the marine transfer area a readily available printed or electronic copy of the most recently examined Operations Manual and Emergency Manual. Electronic devices used to display the manuals must comply with applicable electrical safety standards in this part;

(b) Each transfer operation is conducted in accordance with the examined Operations Manual; and

(c) Each emergency response is in accordance with the examined Emergency Manual.

(a) The operator must designate and mark parking spaces that—

(1) Do not block fire lanes;

(2) Do not impede any exits;

(3) Are not located in any impounding space; and

(4) Are not within 15 meters (49.2 feet) of any storage tank or loading flange.

(b) During transfer operations, no person may—

(1) Stop or park a motor vehicle in a space that is not designated a parking space; or

(2) Refuel any motor vehicle.

(a) The operator must ensure that only the following flammable materials are stored in the marine transfer area for LNG:

(1) LNG.

(2) LPG.

(3) Vessel fuel.

(4) Oily waste from vessels.

(5) Solvents, lubricants, paints, and other fuels in the amount used for one day's operations and maintenance.

(b) Flammable liquids must be stored in accordance with NFPA 30 (incorporated by reference, see § 127.003).

Before transferring LNG, the person in charge of shoreside transfer operations must—

(a) Inspect the transfer piping and equipment to be used during the transfer and replace any worn or inoperable parts;

(b) For each of the vessel's cargo tanks from which cargo will be transferred, note the pressure, temperature, and volume to ensure they are safe for transfer;

(c) Review and agree with the person in charge of cargo transfer on the vessel to—

(1) The sequence of transfer operations;

(2) The transfer rate;

(3) The duties, location, and watches of each person assigned for transfer operations; and

(4) Emergency procedures from the examined Emergency Manual;

(d) Ensure that transfer connections allow the vessel to move to the limits of its moorings without placing strain on the loading arm or transfer piping system;

(e) Ensure that each part of the transfer system is aligned to allow the flow of LNG to the desired location;

(f) Ensure that warning signs that warn that LNG is being transferred, are displayed;

(g) Eliminate all ignition sources in the marine transfer area for LNG;

(h) Ensure that personnel are on duty in accordance with the examined Operations Manual; and

(i) Test the following to determine that they are operable:

(1) The sensing and alarm systems.

(2) The emergency shutdown system.

(3) The communication systems.

(a) After the preliminary transfer inspection under § 127.315 has been satisfactorily completed, the person in charge of shoreside transfer operations must ensure that no person transfers LNG until a Declaration of Inspection that meets paragraph (c) of this section is executed and signed in duplicate.

(b) The person in charge of shoreside transfer operations must give one signed copy of the Declaration of Inspection to the person in charge of transfer operations on the vessel, and must retain one signed copy at the waterfront facility handling LNG for 30 days after completion of the transfer.

(c) Each Declaration of Inspection must contain—

(1) The name of the vessel and the waterfront facility handling LNG;

(2) The date and time that transfer operations begin;

(3) A list of the requirements in § 127.315 with the initials of the person in charge of shoreside transfer operations after each requirement, indicating that the requirement is met;

(4) The signature of the person in charge of shoreside transfer operations and the date and time of signing, indicating that he or she is ready to begin transfer operations; and

(5) The signature of each relief person in charge and the date and time of each relief.

During LNG transfer operations, the following must be met:

(a) The operator of the waterfront facility handling LNG must ensure that—

(1) The marine transfer area for LNG is under the supervision of a person in charge, who has no other assigned duties during the transfer operation;

(2) Personnel transferring fuel or oily waste are not involved in LNG transfer; and

(3) No vessels are moored outboard of any LNG vessel without the permission of the COTP.

(b) The person in charge of shoreside transfer operations must—

(1) Be in continuous communication with the person in charge of transfer operations on the vessel;

(2) Ensure that an inspection of the transfer piping and equipment for leaks, frost, defects, and other symptoms of safety and operational problems is conducted at least once every transfer;

(3) Ensure that transfer operations are discontinued—

(i) Before electrical storms or uncontrolled fires are adjacent to the marine transfer area for LNG; and

(ii) As soon as a fire is detected; and

(4) Ensure that the lighting systems are turned on between sunset and sunrise.

(a) The operator of the waterfront facility handling LNG must ensure that—

(1) No person releases LNG into the navigable waters of the United States; and

(2) If there is a release of LNG, vessels near the facility are notified of the release by the activation of the warning alarm.

(b) If there is a release of LNG, the person in charge of shoreside transfer operations must—

(1) Immediately notify the person in charge of cargo transfer on the vessel of the intent to shutdown;

(2) Shutdown transfer operations;

(3) Notify the COTP of the release; and

(4) Not resume transfer operations until authorized by the COTP.

The operator of the waterfront facility handling LNG must ensure that the equipment required under this part is maintained in a safe condition so that it does not cause a release or ignition of LNG.

The operator must conduct a visual inspection for defects of each pressure-relief device not capable of being tested, at least once each calendar year, with intervals between inspections not exceeding 15 months, and make all repairs in accordance with § 127.405.

The operator must ensure that—

(a) Equipment repairs are made so that—

(1) The equipment continues to meet the applicable requirements in this subpart and in NFPA 59A (incorporated by reference, see § 127.003); and

(2) Safety is not compromised; and

(b) Welding is done in accordance with NFPA 51B and Section 10.4.3 of NFPA 59A (both incorporated by reference, see § 127.003).

(a) The operator must pressure test under paragraph (b) of this section the transfer system, including piping, hoses, and loading arms, and verify the set pressure of the safety and relief valves—

(1) After the system or the valves are altered;

(2) After the system or the valves are repaired;

(3) After any increase in the MAWP; or

(4) For those components that are not continuously kept at cryogenic temperature, at least once each calendar year, with intervals between testing not exceeding 15 months.

(b) The pressure for the transfer system test under paragraph (a) of this section must be at 1.1 times the MAWP and be held for a minimum of 30 minutes.

(a) The operator must keep on file the following information:

(1) A description of the components tested under § 127.407.

(2) The date and results of the test under § 127.407.

(3) A description of any corrective action taken after the test.

(b) The information required by this section must be retained for 24 months.

The training required by this subpart must be completed before LNG is transferred.

The operator shall ensure that each of the following is met:

(a) All full-time employees have training in the following subjects:

(1) Basic LNG firefighting procedures.

(2) LNG properties and hazards.

(b) In addition to the training under paragraph (a) of this section, each person assigned for transfer operations has training in the following subjects:

(1) The examined Operations Manual and examined Emergency Manual.

(2) Advanced LNG firefighting procedures.

(3) Security violations.

(4) LNG vessel design and cargo transfer operations.

(5) LNG release response procedures.

(6) First aid procedures for—

(i) Frostbite;

(ii) Burns;

(iii) Cardio-pulminary resuscitation; and

(iv) Transporting injured personnel.

(c) The personnel who received training under paragraphs (a) and (b) of this section receive refresher training in the same subjects at least once every five years.

(a) Fire equipment and systems provided in addition to the requirements in this subpart must meet the requirements of this subpart.

(b) The following must be red or some other conspicuous color and be in locations that are readily accessible:

(1) Hydrants and standpipes.

(2) Hose stations.

(3) Portable fire extinguishers.

(4) Fire monitors.

(c) Fire equipment, if applicable, must bear the approval of Underwriters Laboratories, Inc., the Factory Mutual Research Corp., or the Coast Guard.

Each marine transfer area for LNG must have—

(a) Portable fire extinguishers that meet Section 16.6.1 of NFPA 59A and Chapter 6 of NFPA 10 (both incorporated by reference, see § 127.003); and

(b) At least one portable fire extinguisher in each designated parking area.

(a) There must be an emergency outfit for each person whose duties include fighting fires, but there must be at least two emergency outfits. Each emergency outfit must include—

(1) One explosion-proof flashlight;

(2) Boots and gloves of rubber or other electrically nonconducting material;

(3) A rigid helmet that protects the head against impact;

(4) Water resistant clothing that also protects the body against fire; and

(5) U.S. Bureau of Mines approved self-contained breathing apparatus.

(b) Emergency outfits under paragraph (a) of this section must be in locations that are readily accessible and marked for easy recognition.

(a) Each marine transfer area for LNG must have a fire main system that provides at least two water streams to each part of the LNG transfer piping and connections, one of which must be from a single length of hose or from a fire monitor.

(b) The fire main must have at least one isolation valve at each branch connection and at least one isolation valve downstream of each branch connection to isolate damaged sections.

(c) The fire main system must have the capacity to supply—

(1) Simultaneously all fire hydrants, standpipes, and fire monitors in the system; and

(2) At a Pitot tube pressure of 618 kilonewtons per square meter (75 p.s.i.), the two outlets having the greatest pressure drop between the source of water and the hose or monitor nozzle, when only those two outlets are open.

(d) If the source of water for the fire main system is capable of supplying a pressure greater than the system's design working pressure, the system must have at least one pressure relief device.

(e) Each fire hydrant or standpipe must have at least one length of hose of sufficient length to meet paragraph (a) of this section.

(f) Each length of hose must—

(1) Be 1 1/2 inches or more in diameter and 30.5 meters (100 feet) or less in length;

(2) Be on a hose rack or reel;

(3) Be connected to the hydrant or standpipe at all times; and

(4) Have a Coast Guard approved combination solid stream and water spray fire hose nozzle.

(a) Each marine transfer area for LNG must have a dry chemical system that provides at least two dry chemical discharges to the area surrounding the loading arms, one of which must be—

(1) From a monitor; and

(2) Actuated and, except for pre-aimed monitors, controlled from a location other than the monitor location.

(b) The dry chemical system must have the capacity to supply simultaneously or sequentially each hose or monitor in the system for 45 seconds.

(c) Each dry chemical hose station must have at least one length of hose that—

(1) Is on a hose rack or reel; and

(2) Has a nozzle with a valve that starts and stops the flow of dry chemical.

The marine transfer area for LNG must have an international shore connection that is in accordance with ASTM F1121-87 (Reapproved 2019) (incorporated by reference, see § 127.003), a 2 1/2 inch fire hydrant, and 2 1/2 inch fire hose of sufficient length to connect the fire hydrant to the international shore connection on the vessel.

In the marine transfer area for LNG, the operator must ensure that no person smokes when there is LNG present.

In the marine transfer area for LNG, the operator must ensure that there are no fires when there is LNG present.

The operator must ensure that no person conducts welding, torch cutting, or other hotwork unless that person has a permit from the COTP.