Chapter 1
Introduction
This chapter
provides an overview of the
liquefied gases carried
by sea and it concludes with some advice on the safety issues
involving the ship, the terminal and the
ship/shore interface. The latter point is of the utmost importance as this is where ship and shore personnel meet to plan safe operations. Subsequent chapters provide much greater detail about gas carrier
cargoes and the equipment utilised
on the ship and at the terminal jetty. They
also cover operational and emergency procedures. Questions of health and safety are
also
covered and Chapter Six is devoted exclusively to
ship/shore interface
matters.
A thorough understanding of the basic principles outlined
in this book is recom- mended as such knowledge will help ensure safer operations, better
cargo planning and the efficient use of equipment
found on gas carriers and on jetties.
1.1 LIQUEFIED GASES
A liquefied gas is the liquid form of a substance which, at ambient temperature and at atmospheric pressure, would be a gas.
Most liquefied gases are hydrocarbons
and the key property that makes hydrocarbons the world’s primary energy source — combustibility — also makes them inherently
hazardous. Because these gases are handled in large quantities it is imperative that all
practical steps are taken to minimise leakage and to limit all sources of ignition.
The most important property of a liquefied
gas, in relation to pumping
and storage, is its saturated vapour pressure. This is the absolute pressure (see 2.15) exerted
when the liquid is in equilibrium with its own vapour at a given temperature. The International Maritime Organization (IMO), for the purposes of its Gas Carrier Codes (see Chapter Three), relates saturated
vapour pressure to
temperature
and has adopted
the following
definition for the liquefied gases carried by sea:
Liquids with a vapour pressure exceeding
2.8 bar absolute at a temperature of 37.8°C
An alternative way of describing a liquefied
gas is to give the temperature at which the saturated
vapour pressure is equal to atmospheric
pressure — in other words the liquid’s atmospheric boiling point.
In Table 1.1 some liquefied
gases carried at sea are compared in terms of their vapour pressure
at 37.8°C — the IMO
definition — and in terms of their atmospheric boiling points.
Table 1.1
Physical properties of some liquefied
gases
Liquefied gas
|
Vapour pressure at 37.8°C
(bars absolute)
|
Boiling point
at atmospheric pressure
(°C)
|
Methane
|
Gas*
|
–161.5
|
Propane
|
12.9
|
–42.3
|
n-Butane
|
3.6
|
–0.5
|
Ammonia
|
14.7
|
–33.4
|
Vinyl chloride
|
5.7
|
–13.8
|
Butadiene
|
4.0
|
–5
|
Ethylene oxide
|
2.7
|
+10.7
|
* The critical
temperature of methane
is –82.5°C while the critical pressure is 44.7 bars. Therefore, at a temperature of 37.8°C it can only exist as a gas and not as a liquid.
On the basis of the above IMO definition, ethylene oxide (see
Table 1.1) would not qualify as a
liquefied gas. However, it is included in the International
Code
for the Construction and Equipment of Ships Carrying Liquefied Gases in Bulk (the IGC Code)
because its boiling point at atmospheric pressure is so low that it would be difficult to carry the cargo by any method other than those prescribed
for liquefied gases.
Likewise, chemicals such
as diethyl ether, propylene
oxide and isoprene are not strictly
liquefied gases but they have
high
vapour pressures coupled with health and flammability hazards. As
a result of such dangers these chemicals, and several similar
compounds, have been listed jointly in both the IGC Code and the Bulk Chemical Codes. Indeed, when transported on chemical
tankers, under the terms of the Bulk Chemical Codes, such products are often required to be stowed in independent tanks rather than in tanks built into the ship’s structure.
1.2 LIQUEFIED GAS PRODUCTION
To assist in understanding the various terms used in the gas trade, this
section discusses the manufacture of liquefied gases and describes
the main gas carrier cargoes transported by sea. It is first of all necessary to differentiate between some of the raw materials and their
constituents and in
this
regard the relationships between natural gas, natural gas liquids
(NGLs) and Liquefied
Petroleum Gases (LPGs) is shown
in Figure 1.1
Figure 1.1 Constituents of natural gas
1.2.1 LNG production
Natural gas may be found in:
• Underground wells, which are mainly gas bearing (non-associated gas)
• Condensate reservoirs
(pentanes and heavier
hydrocarbons)
• Large oil fields (associated gas)
In the case of oil wells, natural
gas
may be either in solution
with the crude oil or as a gas-cap above it.
Natural gas contains smaller quantities
of heavier hydrocarbons (collectively known as
natural gas liquids
— NGLs). This is in addition to varying amounts of water, carbon dioxide, nitrogen
and other
non-hydrocarbon substances.
These relationships
are
shown in Figure 1.1.
The proportion
of NGL contained
in raw natural
gas varies from
one location to another. However, NGL percentages are generally smaller in gas wells when com- pared with those found in condensate reservoirs or that associated with crude oil. Regardless
of
origin, natural gas requires treatment to remove heavier hydrocarbons and non-hydrocarbon
constituents. This ensures
that
the product is in an acceptable condition for liquefaction or for use as a gaseous
fuel.
Figure 1.2 is a typical flow diagram for a liquefaction plant used to produce liquefied natural gas (LNG). The
raw
feed gas is first stripped of condensates. This is followed by the removal of acid gases (carbon dioxide and hydrogen sulphide). Carbon dioxide must be removed as it freezes at a temperature above the atmospheric boiling point of LNG and the
toxic compound
hydrogen sulphide
is removed as it causes atmospheric pollution when being burnt in a fuel. Acid gas removal saturates
the gas stream with water vapour and this is then removed by the dehydration unit.
Figure 1.2 Typical
flow diagram for LNG liquefaction
The
gas
then passes to a fractionating unit where the NGLs are removed and further split into propane and butane.
Finally, the main gas flow, now mostly methane,
is liquefied into the end product, liquefied natural gas (LNG).
To
lower the temperature of the methane gas to about –162°C (its atmospheric boiling point) there are three basic liquefaction processes in current use. These
are outlined below:—
• Pure refrigerant
cascade process — this is similar in principle
to the cascade reliquefaction cycle described in 4.5 but in order to reach the low temperature required, three
stages
are involved, each having its own refrigerant, compressor and heat exchangers. The first
cooling stage utilises propane,
the second is a condensation stage utilising ethylene and, finally, a sub-cooling stage utilising methane is involved. The
cascade process is used in plants commissioned before 1970.
• Mixed
refrigerant
process — whereas
with pure refrigerant process (as
described above) a series of separate
cycles are involved,
with the mixed refrigerant
process (usually methane, ethane, propane and nitrogen), the entire process is achieved in one cycle. The equipment is less complex than the pure refrigerant cascade process but power consumption
is substantially greater
and for this reason its use is not widespread.
• Pre-cooled mixed refrigerant
process — this process is generally
known as the MCR process (Multi-Component Refrigerant) and is a combination of the pure refrigerant cascade
and mixed refrigerant
cycles. It is by far
the
most common process in use today.
Fuel for the plant is provided mainly by flash-off gas from the reliquefaction process but boil-off from LNG storage tanks can also be used. If necessary, additional fuel may be taken from raw feed gas or from extracted
condensates. Depending upon the characteristics of the LNG
to be produced and the requirements of the trade, some of the extracted NGLs may be re-injected
into the LNG stream.
1.2.2 LPG production
Liquefied petroleum gas (LPG) is the general name given for propane, butane and mixtures of the two. These products can be obtained from the refining of crude oil. When produced in this way they are usually manufactured in pressurised
form.
However, the main production
of LPG is found within petroleum producing countries. At these locations,
LPG is extracted from natural gas or crude oil streams coming from underground reservoirs. In the case of a natural gas well, the raw product
consists mainly of methane. However, as shown in Figure 1.2, in this process it is normal for NGLs to be produced and LPG may be extracted
from them as a by-product.
A simple flow diagram which illustrates the production of propane and butane from oil and gas reservoirs
is shown in Figure 1.3. In this example the methane and ethane
which have been removed are used by the terminal’s power station, and the LPGs,
after fractionation and chill-down,
are pumped
to terminal storage
tanks prior
to shipment
for export.
Figure 1.3 Typical
oil/gas flow diagram
1.2.3 Production
of chemical gases
A simplified
diagram for the production of the chemical gases, vinyl chloride, ethylene
and ammonia is shown in Figure 1.4. These
three chemical
gases can be produced indirectly from propane. The propane is first cracked catalytically into methane and ethylene. The
ethylene stream can then be synthesised with chlorine to manufacture vinyl chloride.
In the case of the methane stream, this is first reformed with steam into hydrogen.
By
combining this with nitrogen under high pressure and
temperature, in the presence of a catalyst,
ammonia is produced.
Figure 1.4 Typical flow diagram
— production of chemical
gas
1.2.4 The principal
products
Whilst the hydrocarbon
gases methane, ethane, propane and butane may be regarded principally as fuels,
the
LPGs are also important as feedstocks in
the
production of the chemical
gases.
Liquefied Natural Gas (LNG), Natural gas is transported either by pipeline as a gas or by sea in its liquefied form asLNG.
Natural gas comes from underground deposits as described
in 1.2.1. Its composition varies according
to where it is found but methane is by far the predominant con- stituent, ranging from
70 per
cent to
99 per
cent. Natural gas
is now
a
major commodity in the world energy market and approximately 73 million tonnes are carried by sea each year. This is expected to increase to 100 million tonnes per year by the end of the millennium.
Natural Gas Liquids
(NGLs), Associated gas, found in combination with crude oil, comprises mainly methane and
NGLs. As shown in Figure 1.1, the NGLs are made up of ethane, LPGs and gasoline.
A small number of terminals, including several
facilities in Europe, have the ability to strip methane from the gas stream and to load raw NGLs
onto
semi-pressurised gas carriers. These ships are modified
with additional compressor capacity for shipment to customers able to accept such ethane-rich cargoes. These NGLs are carried
at
–80°C at atmospheric pressure or at –45°C at a vapour pressure of 5bar.
The Liquefied Petroleum Gases (LPG), The
liquefied petroleum gases comprise propane, butane and mixtures of the two. Butane stored in cylinders and thus known as bottled gas, has widespread use as a fuel for heating and cooking
in remote locations. However, it is also an important octane enhancer
for motor gasoline and a key petrochemical
feedstock. Propane, too, is utilised as
a bottled gas, especially in cold climates (to
which its vapour pressure is
more suited). However, LPG is mainly used
in power
generation, for industrial purposes such as
metal cutting and as
a petrochemical feedstock. About 169 million tonnes of LPG are produced
each year worldwide and, of this, about 43.7 million tonnes are transported by sea.
Ammonia, With increased pressure on the world’s
food
resources, the demand for nitrogen- containing
fertilisers, based on ammonia, expanded strongly during the 1970s and
1980s. Large-scale ammonia
plants continue to be built in locations rich in
natural gas which is the raw material most commonly used
to
make this product. Ammonia is
also used as an on-shore industrial
refrigerant, in the production
of explosives and for numerous industrial chemicals such as urea. Worldwide
consumption of this major
inorganic base chemical in 1996 was 120 million tonnes. About 12 million tonnes of ammonia are shipped by sea each year in large parcels on fully refrigerated carriers
and this accounts
for the third largest seaborne trade in liquefied
gases — after LNG and LPG.
Ethylene, Ethylene is one of the primary petrochemical building blocks. It is used in the manu- facture of polyethylene plastics, ethyl alcohol,
polyvinyl chloride
(PVC), antifreeze,
polystyrene and polyester
fibres. It is obtained by cracking either naphtha, ethane
or LPG. About 85 million tonnes of ethylene
is produced
worldwide each year but, because most of this output is utilised close to the point of manufacture, only some
2.5 million tonnes is moved long distances by sea on semi-pressurised carriers.
Propylene, Propylene is a petrochemical
intermediate used to make polypropylene and poly- urethane
plastics, acrylic fibres and industrial solvents. As of mid-1996, annual
worldwide production
of propylene
was 42 million
tonnes, with about
1.5 million tonnes of this total being carried by semi-pressurised
ships on deep-sea routes.
Butadiene, Butadiene is a highly reactive
petrochemical intermediate. It is used to produce styrene,
acrylonitrile and polybutadiene synthetic rubbers. Butadiene is also
used
in paints and binders for non-woven fabrics and, as an intermediate, in plastic and nylon production. Most butadiene output stems from the cracking of naphtha to produce ethylene.
Worldwide total production of Butadiene in 1996 was 6.9 million tonnes. About 800,000 tonnes of butadiene is traded by sea each year.
Vinyl chloride, Vinyl chloride is an easily liquefiable, chlorinated gas used in the manufacture of PVC, the
second
most important
thermoplastic in the world in terms
of output.
Vinyl
chloride not only has a relatively
high boiling point, at
–14°C, but is also, with a specific gravity of 0.97, much denser than the other common gas carrier
cargoes. Worldwide production of vinyl
chloride in 1996 was
22.3 million tonnes. Some 2 million tonnes of vinyl chloride is carried by sea each year.
1.3 TYPES OF GAS CARRIERS
Gas carriers range in capacity from the small pressurised ships of between 500 and
6,000 m3 for the shipment of propane, butane and the chemical gases at ambient
temperature up to the fully insulated
or refrigerated ships of over 100,000 m3 capacity
for the transport of LNG and LPG. Between these two distinct types is a third ship type
— the semi-pressurised gas carrier. These
very flexible ships are able to carry many
cargoes in a fully refrigerated condition at atmospheric pressure or at temperatures
corresponding to carriage pressures of between
five and nine bar.
The movement of liquefied gases by sea is now a mature industry, served by a fleet of over 1,000 ships, a worldwide network of export and import terminals and a wealth of knowledge and
experience on the part of the various people involved.
In 1996 this fleet transported
about
62.5 million tonnes of LPG and chemical gases and 73 million tonnes of LNG. In the same year the ship numbers in each fleet were approximately as follows:—
• LNG carriers
|
105
|
• Fully refrigerated ships
|
183
|
• Ethylene carriers
|
100
|
• Semi-pressurised ships
|
276
|
• Pressurised ships
|
437
|
Gas
carriers have certain
design features in common with other ships used for the carriage
of bulk liquids
such as oil and chemical
tankers. Chemical tankers carry their
most hazardous cargoes in centre tanks,
whilst cargoes of lesser danger can be shipped in the wing tanks. New oil tankers are required to have wing and double bottom
ballast tanks located to give protection to the cargo. The objective in both these cases is to protect against the spillage of hazardous cargo in the event of a grounding or collision. This same principle
is applied to gas carriers.
A feature almost unique to the gas carrier
is that the cargo tanks are kept under positive pressure to prevent air entering the cargo system. This means that only cargo liquid and cargo vapour are
present in the cargo tank and flammable
atmospheres cannot develop.
Furthermore all
gas carriers
utilise closed
cargo systems
when loading or discharging, with no venting of vapours being allowed to the atmosphere. In the LNG trade, provision is always made for the use of a vapour return line between ship and shore to pass vapour displaced by the cargo transfer. In the LPG trade this is not always the case as, under normal circumstances
during loading, reliquefaction is used to retain vapour on board. By these
means cargo release to the atmosphere is
virtually eliminated
and the risk of vapour ignition is minimised.
Gas
carriers must comply with the standards set by the International Maritime Organization in the Gas Codes (see Chapter Three), and with all safety and pollution requirements common to other ships. The Gas Codes are a major pro-active
feature in IMO’s legislative programme. The
safety features inherent in the Gas Codes’ ship design requirements have helped considerably in the safety of these ships. Equipment requirements for
gas carriers
include temperature and
pressure
monitoring, gas
detection and cargo tank liquid level indicators, all of which are provided with alarms
and ancillary instrumentation. The variation
of equipment as fitted can make the gas
carrier one of the most sophisticated ships afloat today.
There is much variation in the design, construction and operation of gas carriers due to the variety
of cargoes carried and the
number
of cargo
containment systems utilised. Cargo
containment systems may
be
of the independent tanks (pressurised,
semi-pressurised
or fully refrigerated) or of the membrane type (see
3.2.2). Some of the principal features of these
design variations and a short history of each trade are
described below.
Fully pressurised ships, The
seaborne transport of liquefied gases began in 1934 when a major international company put two combined oil/LPG tankers into operation. The
ships, basically oil tankers, had been
converted by fitting small, riveted, pressure vessels for the carriage of LPG into cargo tank spaces. This enabled transport
over long distances of sub- stantial
volumes of
an oil refinery by-product that
had distinct
advantages as a domestic
and commercial fuel. LPG
is
not only odourless and non-toxic, it also has a high calorific value and a low sulphur content, making it very clean and efficient when
being burnt.
Today, most fully pressurised LPG carriers are fitted with
two or three horizontal, cylindrical or spherical cargo tanks and have
capacities up to 6,000 m3. However, in recent years a number of larger
capacity fully-pressurised
ships have been built with spherical tanks,
most notably
a pair
of 10,000 m3 ships, each incorporating five spheres, built by a Japanese shipyard in 1987. Fully pressurised
ships are still being built in numbers and represent a cost-effective, simple way of moving LPG to and from smaller gas terminals.
Semi-pressurised ships, Despite the early breakthrough with the transport of pressurised LPG,
ocean move- ments of liquefied
gases did not really begin to grow until the early 1960s with the development of metals suitable for the containment of liquefied gases
at low temperatures. By
installing a reliquefaction plant, insulating
the cargo
tanks and making use of special steels, the shell thickness of the pressure vessels, and hence
their weight, could be reduced.
The
first ships to use this new technology appeared in 1961. They carried gases in a semi-pressurised/semi-refrigerated
(SP/SR) state but further advances
were quickly made and by the late 1960s semi-pressurised/fully refrigerated (SP/FR) gas carriers
had become the shipowners’
choice by providing high flexibility in cargo handling.
Throughout this
book the SP/FR ships are referred to as semi-pressurised
ships. These carriers,
incorporating tanks either cylindrical, spherical or bi-lobe in shape, are able
to load or discharge gas cargoes at both refrigerated and pressurised storage facilities.
The existing
fleet of
semi-pressurised ships
comprises carriers
in the
3,000-15,000 m3 size range, although there is a notable exception — a ship of 30,000
m3 delivered in 1985.
Ethylene and gas/chemical carriers, Ethylene carriers
are the most sophisticated of the semi-pressurised tankers and have the ability to carry not only most other liquefied
gas cargoes but also ethylene
at
its atmospheric boiling point of –104°C. The first ethylene carrier was built in 1966 and, as of 1995, there were about 100 such ships in service ranging in capacity
from 1,000 to 12,000 m3.
Of this ethylene carrier
fleet, about one dozen form a special sub-group of ships able to handle a wide range of liquid chemicals
and liquefied gases simultaneously. These ships feature cylindrical, insulated, stainless
steel cargo tanks able to accommodate cargoes up to
a maximum specific
gravity
of 1.8 at temperatures ranging from
a
minimum of –104°C to a maximum of +80°C and at a maximum tank pressure of 4 bar. The ships can load or discharge at virtually
all pressurised and refrigerated terminals, making them the most versatile gas carriers in terms of cargo-handling ability.
Fully refrigerated ships, The 1960s
also saw
another major
development in gas
carrier
evolution. the appearance
of the first fully refrigerated ship, built to carry liquefied gases at low temperature and atmospheric pressure between terminals equipped
with fully refrigerated storage tanks. The first purpose-built, fully refrigerated LPG carrier was
constructed by a
Japanese shipyard, to a United States design, in 1962. The ship had four prismatic-shaped (box-like)
cargo tanks fabricated
from 31⁄2 per cent nickel steel,
allowing the carriage
of cargoes at temperatures as low as –48°C, marginally below the atmospheric
boiling
point of pure propane. Prismatic
tanks enabled the ship’s cargo carrying capacity to be maximised, thus making fully refrigerated ships highly suitable for carrying large volumes of cargo such as LPG, ammonia and vinyl chloride over long distances. Today, fully refrigerated ships range in capacity from 20,000 to 100,000 m3.
The
main types
of cargo
containment system utilised
on board modern fully refrigerated ships are independent tanks having rigid foam insulation. Older ships can have independent tanks with loosly
filled perlite insulation. In the
past, there have been a few fully refrigerated ships built with semi-membrane or integral tanks and internal
insulation tanks, but these systems have only maintained
minimal interest.
Liquefied natural gas (LNG) carriers, At about the same time as the development of fully refrigerated LPG carriers was
taking place, naval architects
were facing their most demanding gas
carrier challenge. This was the transport
of LNG. Natural
gas, another clean, non-toxic fuel, is now the third most
important energy source in the
world, after oil and
coal, but is often produced
far from the centres of consumption. Because a gas in its liquefied
form occupies much
less space, and
because
of the critical temperature of liquefied methane, the ocean transport of LNG only makes sense from a commercial viewpoint if it is carried in a
liquefied state at atmospheric pressure; as
such, it represents a
greater engineering challenge than shipping
LPG, mainly because it has to be carried at a much lower temperature; its boiling
point being –162°C.
The pioneering cargo of LNG was carried across the Atlantic Ocean in 1958 and by
1964
the first
purpose-built LNG carriers
were in
service under a long-term gas
purchase agreement.
LNG containment system technology has developed consider-
ably since those early days: now about one-half of the LNG carriers in service are fitted
with independent cargo tanks and one-half
with membrane tanks. The majority of LNG
carriers are between
125,000 and 135,000 m3 in capacity. In the modern fleet of LNG
carriers, there is an interesting exception concerning ship size. This is the introduction
of several smaller ships of between 18,000 and 19,000 m3 having been built in 1994
and later to service the needs of importers of smaller volumes.
1.4 THE SHIP/SHORE INTERFACE AND JETTY STANDARDS
In comparison to most other ship types, gas carriers have a better safety record. However, casualty
statistics involving gas carriers
demonstrate that the risk of a serious accident
is potentially greater when the ship is in port than when at sea. For this reason it is appropriate that attention
should concentrate on the port facilities and the activities of ship and shore personnel
involved in cargo operations.
1.4.1 Safe jetty
designs
The ship/shore interface
is a vital area for consideration in the safety of the liquefied gas trade. Considering jetty design (and the equipment which may be needed), safety
in this area requires a good
understanding of ship parameters before construction begins. In
this context the
following points are often
addressed by
terminal designers:—
• The berth’s safe
position regarding other marine traffic
• The berth’s safe
position in relation to adjacent industry
• Elimination of nearby ignition sources
• Safety distances between adjacent ships
• The range of acceptable ship sizes
• Ships’ parallel body length — for breasting dolphin
positioning
• Suitable jetty fender designs
• Properly positioned shore mooring
points of suitable strength
• Tension-monitoring equipment for mooring line loads
• Suitable water depths at the jetty
• Indicators for ship’s speed of approach to the jetty
• The use of hard arms and their safe
operating envelopes
• Emergency shut-down systems — including
interlinked ship/shore control
• Suitable plugs and sockets for the ship/shore link
• A powered emergency release coupling on the hard arm
• Vapour return facilities
• Nitrogen supply to the jetty
• Systems for gas-leak detection
• A safe
position for ship/shore gangway
• Design to limit surge pressures in cargo pipelines
• Verbal communication systems
• The development of Jetty Information and Regulations
• Jetty life saving and fire-fighting equipment
• Systems for the warning of the onset of bad weather
• The development of Emergency Procedures
Further issues have to be considered in the port approach. These may include the suitability of Vessel Traffic Management Systems, and the sizing of fairways and turn- ing basins. However, these latter points fall outside
of the scope of this publication.
1.4.2 Jetty operations
The ship/shore interface
is the area where activities
of personnel on the ship and shore overlap during cargo handling. Actions on one side of the interface will affect the other party and responsibility for safe
operations does not stop at the cargo manifold for either ship or shore personnel.
The responsibility for cargo handling operations is shared between the ship and the terminal and rests jointly
with the shipmaster and
responsible terminal representative. The
manner in which the responsibility is shared
should, therefore, be agreed between them so as to ensure
that
all aspects of the operations are covered.
From an operational viewpoint it should be appreciated that at the ship/shore inter- face two differing cultures co-exist. To ensure safe operations, a proper understand- ing of the working practices
of both ship and shore personnel
is necessary. Equally, before and during operations, procedures of practical relevance have to be in place and jointly
understood by ship and shore personnel.
Most often this is best achieved
by properly addressing the Ship/Shore Safety Check List (see
Appendix 3) and this should be supplemented by a suitable
terminal operating manual, containing Jetty Information and Regulations, which should be passed to the ship.
There is much variation in the design and operation of terminals and jetties and not all are dedicated
solely to the handling of liquefied gases. Sometimes the combined nature of
the products handled
can complicate
operations. Equally, however,
variations in gas carrier and jetty construction can heighten the importance of safety
issues at the interface,
making them an important area
requiring proper controls and good operational procedures.
LPG berths
may have to handle ships of varying size
and
having a range of different cargo handling
equipment. Jetties may be relatively
new, and fitted with modern cargo facilities. Conversely, they may be relatively old using flexible hoses for cargo transfer. Of course, many jetties fall between these two extremes. At LPG
berths, local design variation
at the
ship/shore connection may
result
in the need to use either hoses or all- metal hard arms. The hard arm may be hydraulically operated: it may be fitted with emergency release couplings
and an emergency release system.
LNG terminals are an exception
to the foregoing — they are primarily dedicated to this single product,
although
some LNG jetties also handle LPGs and condensates. In most
cases such
berths have been
specially built
for a particular
export/import project. LNG jetties only use hard arms for cargo transfer. The hard arm is invariably hydraulically operated.
Almost certainly it will be fitted with emergency release couplings and an emergency release system.
Liquefied gas cargo
handling
procedures
can be complex and the cargo
itself
is potentially hazardous. For these reasons, the persons operating gas carriers and gas
berths require a thorough understanding
of ship and shore equipment and cargo properties.
They need to have available
good operating procedures so as to avoid accident and emergency plans should be in place in case an accident does occur.
For ships’ personnel,
much of this information is made available
by means of ap- proved courses
to obtain dangerous cargo endorsements for sea-going certificates. For terminal personnel, such background may be available at national institutions; alternatively, terminal managements may find References 2.19 and 2.32 of benefit.
Source : SIGTTO Personal Handbook.
