2. Content
• History
• Global Production and consumption
• Future outlook
• Pricing
• Natural gas contracts
• Transportation- Pipeline
• Pipeline- Tariffs, Transit systems
• LNG- InCoterms, Cargo
3. Historical perspective
• Natural gas is nothing new. In fact, most of the
natural gas that is brought out from under the
ground is millions and millions of years old.
• lightning strikes would ignite natural gas that was
escaping from under the earth’s crust. This would
create a fire coming from the earth, and were the
root of myth and superstition. One of the most
famous of these flames was found in ancient
Greece, on Mount Parnassus around 1000 B.C. A
goat herdsman came across what looked like a
‘burning spring’
4. • About 500 B.C. that the Chinese discovered the
potential to use these fires to their advantage.
Finding places where gas was seeping to the
surface, the Chinese formed crude pipelines out of
bamboo shoots to transport the gas, where it was
used to boil sea water, separating the salt and
making it palatable.
• In 1821, the first well specifically intended to obtain
natural gas was dug in Fredonia, New York by
William Hart. After noticing gas bubbles rising to
the surface of a creek, Hart dug a 27-foot well to try
and obtain a larger flow of gas to the surface. Hart
is regarded by many as the ‘father of natural gas’ in
America.
5. • For most of the 1800s, natural gas was used
almost exclusively as a fuel for lamps. Because
there were no pipelines to bring gas into
individual homes, most of the gas went to light
city streets. After the 1890s, however, many
cities began converting their street lamps to
electricity. Gas producers began looking for
new markets for their product.
• In 1885, Robert Bunsen invented a burner that
mixed air with natural gas. The “Bunsen
burner” showed how gas could be used to
provide heat for cooking and warming buildings.
6. Natural Gas today
• It took the construction of pipelines to bring natural gas
to new markets. Although one of the first lengthy
pipelines was built in 1891 – it was 120 miles long and
carried gas from fields in central Indiana to Chicago –
there were very few pipelines built until after World War
II in the 1940s.
• Improvements in metals, welding techniques and pipe
making during the War made pipeline construction more
economically attractive. After World War II, the nation
began building its pipeline network. Throughout the
1950s and 1960s, thousands of miles of pipeline were
constructed throughout the United States. Today, the
U.S. pipeline network, laid end-to-end, would stretch to
the moon and back twice.
7. Supply and Production
• From a global perspective, proved reserves of natur
al gas have continually increased over the last sever
al decades, while natural gas production as a perce
ntage of reserves has generally decreased
24. Hub Based Systems
• Supply and demand set at liquid Hubs. In north
America, the most important price marker is henry
Hub (Louisiana), with a spot and futures market
trading on the New York Mercantile Exchange
(NYMEX). In Europe, the most important hub is
national balancing Point (NBP) in the United
Kingdom, Which is virtual trading point for the
international exchange (ICE). It contains both a spot
and futures market, although prices fall sharply
after the first few months of future delivery.
26. Oil-Linked Systems
• Most of the gas traded in Europe and Asia and
specifically long term LNG contracts fall in this
category
• Gas contracts formulas vary in a number of ways
based on the following factors.
• Indexation
• Slope/Coefficients of the Indexation
• Presence of S-Curves
• Lag and averaging mechanisms
27. Regulated Systems
• In many parts of the world prices are regulated
• In this case the government sets wellhead,
transportation and end-user prices
28. Subsidized
• In most countries in the middle east and North
Africa, Gas prices barely suffice to cover production
cost
• In Latin America, The former Soviet Union and in
much of Africa, gas prices are similarly set with no
linkage to Oil or costs
30. (1) Short term spot contracts
• Spot price: “The price for a one-time open market transaction for
immediate delivery of a specific quantity of product at
a specific location where the commodity is purchased
‘on the spot’ at current market rates”
• Immediate sale/purchase of the commodity (30 days in natural gas)
• Gas reservoirs best fitting the short-term revenue source:
1. Reservoir in which the producer is under-produced
2. New reservoir that can be connected within a short period of time
3. Reservoir that must produce every day (associated gas).
• Natural gas spot trading began on a large national scale during 1983.
• Spot prices have become seasonal, peaking sharply during the winter
demand period, and again during summer periods of peak electricity
generation, caused by demand for air conditioning.
• Risky for buyer as natural disasters and global politics can spark huge
price fluctuations or volatility.
31. • Begins in middle of the month, gas marketers, sellers, and
buyers communicate regarding possible gas purchase/sales
transactions that will take place during the following month.
• Marketers tentatively arrange to purchase gas supplies from
producers, other marketers, or from other sources.
• Approximately ten days before the end of the month, parties
who will secure transportation services from one or more
pipeline(s) submit written preliminary nominations for
transportation capacity to pipelines, identifying gas volumes,
receipt and delivery points, and other key physical and
transactional information.
• Once they have received preliminary nominations for
transportation services as above, pipeline capacity staff
review their nominations and provide feedback to shippers
as to capacity limitations, bottlenecks, and/or similar issues.
Spot Market Transaction Cycle
32. Spot Market Transaction Cycle
cont.
• During the last full week before the end of the month
("bid week"), buyers, sellers, and marketers again
communicate with one another regarding gas volumes
and prices to be agreed upon in thousands of individual
transactions scheduled to flow during the following
month.
• Shippers notify pipelines in writing as to final
nominations and gas routing, based on feedback
received from preliminary nominations and on needs
developed subsequently in market negotiations
• As the month ends, the business enters a "cleanup"
phase in which the final transactions are completed for
the new month, and final transportation arrangements
are made.
33. (2) Fixed—Term Interruptible Multi—
Month Contracts
• Early in the development of the spot market, transactions typically were
conducted on a limited-term "interruptible" basis.
• If a buyer desired to purchase a quantity of gas and the seller had gas
available for sale, a deal would be struck at a mutually agreed upon price
for a given volume taken by the purchaser during a given month.
• Because quantity was interruptible, neither party considered itself legally
obligated to purchase or sell any specific quantity of gas.
• Rather than enter into a new agreement every month, the limited term
interruptible arrangement evolved over time to cover multiple months.
• The seller might indicate periodically that it had a package of gas available
for sale.
• The buyer would nominate a volume it desired purchasing, if any, and the
price at which it was willing to pay.
• The basic difference from the spot market is that the purchaser and/or
producer can decline any sale or purchase prior to sale consummation.
34. (3) Longer-Term or Warranty Sales
in Gas Contracts
• Warranty contracts characteristically call for the
producer to guarantee that it will make available for
sale a fixed quantity of gas each month.
• It generally is for a primary term of five years or
longer.
• Greater risks associated with such contracts; more
time has to be spent on negotiating and drafting.
• With pipeline open access becoming more universal,
producer-marketers are beginning to shift their
emphasis from spot sales to term contracting.
35. Depletion contract
• A nominated gas field dedicated to the Buyer
• Contract quantities based on economically
recoverable reserves
• No obligation on Seller to secure additional
reserves to meet supply obligation
36. Supply contract
• Seller commits to deliver a specific quantity of gas
over a period
• Obligation on Seller to secure additional reserves if
initial source of supply is inadequate
37. Take or Pay contract
• Obligation on Buyer to take and pay for, or pay for if not
taken, a minimum quantity of gas within a specified period
of time
• Guarantees the volumes that the Buyer will pay for and
provides Seller with secured revenue stream
• It is the ToPQ Commitment that secures the financing for
the Seller’s project
• Expressed as a percentage of the ACQ (Annual Contract
Quantity) subject to adjustments:
• Non delivered quantities (shortfall)
• Force majeure
• Maintenance
42. Types of Pipeline Transit System
• In general, four kinds of transit system can be distinguished:
• 1) Point to point transit, without connection to and condition from
transiting country.
43. 2) Transit country is also buyer but operated
by separate entity and not the transit country
• TAG (Trans Austria Gas Pipeline) and WAG (Westernport – Altona –
Geelong Pipeline)
• MEGAL (Mittel-Europäische-Gasleitung), TENP(Trans Europa Naturgas
Pipeline)
44. 3) Integrated in to domestic system of transit
country, network owned by transit country
• Ukrainian and Belgian systems
46. Tariff
• A tariff is a fee paid by the customers to a pipeline operator for the
use of the pipelines. It covers the costs of investment and financing,
operating and maintaining the pipe and includes an element of profit
for the operator. These costs may include such items as local taxes
levied on commercial entities. A government charge is a tax levied by
a transit country essentially as a fee for the right of way through that
country’s territory and as compensation for taxes not levied and for
service rendered by the country (e.g. protection of pipeline). It is not
related to costs of transport itself.
• The difference between the two types of payment is that a tariff is
charged based on real costs, whilst a government charge is a tax the
size of which is based on political judgments and negotiations.
47. Types of tariff methodologies
• There are essentially four types of tariff methodologies currently in
use to allocate the overall costs to the shippers.
1) postal;
2) distance-based;
3) point-to-point; and
4) entry/exit.
48. Postal tariffs
• Postal tariffs use a single fixed fee for the transport of any
volume of gas within the area covered by the tariff.
• Advantages:
• They are simple, transparent and are relatively easy for the
new entrants for use.
• Disadvantages:
• They are discriminatory between consumers in different
parts of large systems, given that different amounts of
investment have been required to serve different
consumers.
• They are used domestically in al the non-EU countries except
Russia)
49. Distance-based tariffs
• Under distance-based tariffs, a shipper is required to pay a charge
based on the distance between designated entry and exit points.
• Expressed as $ / m3/h/100 km/year.
• Capacity charge would have to be paid regardless of utilization.
• Where the load factor is high like in most long distance
transportation (transit) systems serving long-term contracts, the
unit used is $/1000m3/100 km.
• Distance-based tariffs have the advantage of being rather simple,
transparent and cost reflective in an apparent way for one
directional flows
• However they are criticized for not being cost reflective in cases
where there is no linear route between entry and exit of gas
• In Europe, this system was used, however, recently they have
been replaced by point to point transit system. However, outside
Europe, distance based tariff system are widely used.
50. Point-to-point tariffs
• In this tariff system, a specific tariff is quoted for every
entry/exit pair within the system.
• This systems are however, highly criticized, because of bring
opaque. They become highly complicated, when there are
multiple entry and exit points in the same pipeline.
• The method is also subject to criticism because of the
portfolio effect and because it fails to provide any clear
signals about capacity constraints at specific points in the
system.
51. Entry Exit Tariffs
• In this tariff system, a separate tariff is quoted for each entry and exit
point. This can be seen as a specific form of point-to-point system.
• Under the entry/exit tariff system, the booking is done separately for
each entry and exit point.
• Entry/exit tarification almost inevitably requires detailed physical and
financial modelling of system flows which can become rather
complex and difficult to understand.
• This system is considerably fair.
• However, in general, a single tariff methodology is no applied, instead
a suitable combination of any two, any three of all of the tariff
methods are put into application.
54. InCoterms
• FOB (=Free on Board), i.e. the gas is deemed “delivered” at the
loading point (the ship) and the buyer becomes responsible for the
shipping.
• DAP (=Delivered at Place) i.e. the gas is deemed “delivered” at the
delivery point.
• The seller remains responsible for the goods until they are delivered
to the destination. However these costs are passed on the buyer.
Sometimes the literature refers to DES which is the old and now
defunct incoterm.
• CIF (=Cost, Insurance, Freight) is similar to DES in that the seller must
arrange the freight, but the difference is that the title is transferred at
point of loading.
• CFR (=Cost and Freight) and is similar to CIF in that the seller must
arrange the freight, but the difference is that the buyer must insure
the cargo.
57. Oil Price linked LNG
• Asian LNG contracts are linked to the crude oil price index. Japan, the
world's largest LNG importer, uses contracts with a formula linked to
the Japanese Customs Cleared Price for crude oil and referred to as
JCC (Japanese Crude Cocktail). With few exceptions, a similar
structure is used in other Asian markets such as South Korea, China,
and Taiwan. The LNG pricing formula for oil-linked LNG contracts is as
follows:
• P= C + βX+ S
P is the LNG price ($/MMBtu)
C is the base price ($/MMBtu)
β is the price slope
X is the Oil Price index (JCC in Japan)
S is the Shipment Charges
58. • Asian oil-linked contracts consist of "S-Curves" within the contract
structures, and within the S-Curve, LNG buyers prefer a flatter slope
at high oil prices while project developers prefer a flatter slope at low
oil price environments to ensure that project economic commitments
are met.
• Typically in an S-Curve-based, oil-linked contract, the price slope is
applied around the $40-to-$100 oil price range, and beyond this
range LNG buyers pay a fixed fee in very high and very low oil price
environments
Although naturally occurring gas has been known since ancient times, its commercial use is relatively recent. In about 1000, B.C., the famous Oracle at Delphi, on Mount Parnassus in ancient Greece, was built where natural gas seeped from the ground in a flame. Around 500 B.C., the Chinese started using crude bamboo “pipelines” to transport gas that seeped to the surface and to use it to boil sea water to get drinkable water.
The first commercialized natural gas occurred in Britain. Around 1785, the British used natural gas produced from coal to light houses and streets. In 1816, Baltimore, Maryland used this type of manufactured natural gas to become the first city in the United States to light its streets with gas.
Naturally occurring natural gas was discovered and identified in America as early as 1626, when French explorers discovered natives igniting gases that were seeping into and around Lake Erie. In 1821, William Hart dug the first successful natural gas well in the U.S. in Fredonia, New York. Eventually, the Fredonia Gas Light Company was formed, becoming the first American natural gas distribution company.
The world's first industrial extraction of natural gas started at Fredonia, New York, United States in 1825
In 1836, the City of Philadelphia created the first municipally owned natural gas distribution company. Today, U.S. public gas systems number more than 900, and the Philadelphia Gas Works is the largest and longest operating public gas system in the U.S
During most of the 19th century, natural gas was used almost exclusively as a source of light, but in 1885, Robert Bunsen's invention of what is now known as the Bunsen burner opened vast new opportunities to use natural gas. Once effective pipelines began to be built in the 20th century, the use of natural gas expanded to home heating and cooking, appliances such as water heaters and oven ranges, manufacturing and processing plants, and boilers to generate electricity.
It took the construction of pipelines to bring natural gas to new markets. Although one of the first lengthy pipelines was built in 1891 -it was 120 miles long and carried gas from fields in central Indiana to Chicago - there were very few pipelines built until after World War II in the 1940s.
Improvements in metals, welding techniques and pipe making during the War made pipeline construction more economically attractive. After World War II, the nation began building its pipeline network. Throughout the 1950s and 1960s, thousands of miles of pipeline were constructed throughout the United States. Today, the U.S. pipeline network, laid end-to-end, would stretch to the moon and back twice.
Today, natural gas is a vital component of the world's supply of energy. Natural gas currently supplies more than one-half of the energy consumed by residential and commercial customers, and about 41 percent of the energy used by U.S. industry. It is one of the cleanest, safest, and most useful of all energy sources.
Ninety-nine percent of the natural gas used in the United States comes from North America. Because natural gas is the cleanest burning fossil fuel, it is playing an increasing role in helping to attain national goals of a cleaner environment, energy security and a more competitive economy. The two million-mile underground natural gas delivery system has an outstanding safety record.
As this 2004 edition of the APGA History Highlights goes to print, liquefied natural gas (LNG) is beginning to play a more prominent role in the overall gas supply picture. Although about one percent of the natural gas consumed in this country is currently imported as LNG, it is estimated that our nation's imports of LNG will grow to approximately 7 or 8% by the end of this decade. This will require more than the four LNG facilities that currently exist.
Explain the Hubs thoroughly
a pipeline crossing sovereign territory and carrying transit gas without any connection to the gas supply system of the transit country. This provides the clearest definition of a transit line, but is rare in practice. The transit lines across Kazakhstan and Uzbekistan from Turkmenistan, the transit through Moldavia and the lines from Algeria across
Morocco are examples of this case, as no or only small amounts of transit gas are delivered to these transit countries.
a transit pipeline which is owned by a separate entity and which is predominantly used for gas transit, but also used to supply gas of the same origin to the transit country. Most of the transit lines for Russian gas (in the former Comecon states) are examples, but also the import project pipelines in from EU-15, such as TAG and WAG lines taking Russian gas across Austria to Italy and Germany respectively and MEGAL taking Russian gas further across Germany, or the TENP taking Dutch gas to Switzerland and Italy. With the new regulation in the EU, some of these lines with regard to the single European market become subject to EU regulation, however with long-term transport commitments reflecting their original purpose.
a transit pipeline system which is integrated into the domestic supply system and which is owned and operated by the main national transmission operator, where the transit gas flow can still be traced. The Ukrainian and Belgian systems are examples of this type of system.
Systems where transit volumes commingle with a highly meshed national grid, (e.g. in UK, Germany and France, and to a lesser extent Italy), which are working like a tub,
where additional inflow just raises the overall level and will be compensated by corresponding output volumes.
Postal tariffs use a single fixed fee for the transport of any volume of gas within the area covered by the tariff. Low-pressure distribution systems invariably use postal tariffs.
The advantages of postal tariffs can be seen precisely in their use in distribution or other highly meshed and concentrated systems; they are simple, transparent and are easy for new entrants to use. This simplicity means that they are often the first tool used by a new regulator when it sets about the complex task of overseeing the gas sector. Effectively, total allowed revenues can be divided by required system capacity, resulting in a unit is a tariff.
However, although postal tariffs continue to be used domestically in all non-EU countries (except Russia, which has a zonal system and by some EU member states, it is recognized that apart from some simple, small systems, postal tariffs have disadvantages. They are discriminatory between consumers in different parts of large systems, given that different amounts of investment have been required to serve different consumers. Moreover, they do not provide signals for efficient use of the system based on spare and tight capacity in different parts of the system. Postal systems may or may not be construed as a capacity charge.
Under distance-based tariffs, a shipper is required to pay a charge based on the distance between designated entry and exit points. They are usually expressed on a booked capacity basis in a dimension of € or $ / m3/h/100 km/year. In a number of Western European systems, the charge varies in relation to the diameter of the pipes used. This capacity charge would have to be paid regardless of utilization. The only element reflecting utilization would be the costs of fuel gas, which often would be supplied in kind. The specific transportation costs would then depend on the utilization factor.
Where the load factor is high like in most long distance transportation (transit) systems serving long-term contracts with a high minimum pay (usually corresponding to at least 7000 hours of full utilization, or a load factor of about 0.8) it may be practical to express the transport tariff in relation to the volumes transported. The unit used in the FSU is $/1000m3 /100 km.
Distance-based tariffs are most useful for systems in which gas moves in one direction for long distances, with rather few intermediate takeoff points. In Europe, they have been used by a number of important systems, though recently they have often been supplanted by entry/exit tariffs for domestic transmission in some EU Member States. Outside the EU, distance tariffs are the norm, though they are usually presented in the form of a commodity charge rather than a capacity charge in view of the high utilisation factor for transit volumes.
In this tariff system, a specific tariff is quoted for every entry/exit pair within the system. The advantage is that tariffs are explicit and should be cost-reflective, provided the system is physically modelled correctly. Nevertheless, this system is criticized for being very opaque. It can also become very complex, if there are a large number of entry and exit points. The method is also subject to criticism because of the portfolio effect and because it fails to provide any clear signals about capacity constraints at specific points in the system. The advantage for the operator is that he will have an overview of the flows requested and the required capacity to serve it.
Type 'B' tanks can be constructed of flat surfaces or they may be of the spherical type. This type of containment system is the subject of much more detailed stress analysis. These controls must include an investigation of fatigue life and a crack propagation analysis.
The most common arrangement of Type 'B' tank is a spherical tank as illustrated in Figure. This tank is of the Kvaerner Moss design. Because of the enhanced design factors, a Type 'B' tank requires only a partial secondary barrier in the form of a drip tray. The hold space in this design is normally filled with dry inert gas. However, when adopting modern practice, it may be filled with dry air provided that inerting of the space can be achieved if the vapour detection system shows cargo leakage. A protective steel dome covers the primary barrier above deck level and insulation is applied to the outside of the tank. The Type 'B' spherical tank is almost exclusively applied to LNG tankers; seldom featuring in the LPG trade.
A Type 'B' tank, however, need not be spherical. There are Type 'B' tanks of prismatic shape in LNG service. The prismatic Type 'B' tank has the benefit of maximising tanker-hull volumetric efficiency and having the entire cargo tank placed beneath the main deck. Where the prismatic shape is used, the maximum design vapour space pressure is, as for Type 'A' tanks, limited to 0.7 barg. A drawing of a self-supporting prismatic Type 'B' tank is shown in Figure 33.2(b).
The concept of the membrane containment system is based on a very thin primary barrier (membrane - 0.7 to 1.5 mm thick) which is supported through the insulation. Such tanks are not self-supporting like the independent tanks outlined in 33.2.1; an inner hull forms the load bearing structure. Membrane containment systems must always be provided with a secondary barrier to ensure the integrity of the total system in the event of primary barrier leakage. The membrane is designed in such a way that thermal expansion or contraction is compensated without over-stressing the membrane itself. There are two principal types of membrane system in common use both named after the companies who developed them and both designed primarily for the carriage of LNG. These two companies have now combined into one and future developments can be expected.
GTT 96 Membrane System
GTT Mk3 membrane System