Gaz ziemny.

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Gaz ziemny.

Wielkość i rozmieszczenie zasobów, rynki energii, bezpieczeństwo

energetyczne, międzynarodowe uwarunkowania wydobycia, transportu i sprzedaży gazu ziemnego.

Przygotował: Mateusz Słupiński, dr inż.

Australia, Austria, Belgium, Canada, the Czech Republic, Denmark, Finland, France, Germany, Greece, Hungary, Iceland, Ireland, Italy, Japan, Korea, Luxembourg, Mexico, the Netherlands, New Zealand, Norway, Poland, Portugal, theSlovak Republic, Spain, Sweden, Switzerland, Turkey, theUnited Kingdom and the United States.

Wprowadzenie - Zużycie energii Gaz ziemny

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Manufacturing 33%

Households 29%

Services 9%

Transport 26%

Other 3%

Total final energy consumption: 285 EJ

Manufacturing 38%

Households 21%

Services 12%

Transport 25%

Other 4%

Total direct and indirect CO emissions: 21 Gt CO₂ ₂ Sources: IEA, 2007c; IEA, 2007d; IEA, 2007e.

Note: Other includes construction and agriculture/fishing.

Figure 2.2 !!!?(7$+!-./$+!0/&%12!3(/'4567.(/!,2!"&;7(%

Sources: IEA, 2007c; IEA, 2007d; IEA estimates.

Note: Other includes construction and agriculture/fishing.

Trends in energy use varied significantly amongst countries and regions (Figure 2.2).

Between 1990 and 2005, final energy use grew less quickly in OECD countries (+19%) than in non-OECD countries (+27%). In OECD countries, the growth was mostly due to increasing transport energy consumption. In 2005, the transport sector accounted for

0 10 20 30 40 50 60 70

EJ

1990 2005 1990 2005 1990 2005 1990 2005 1990 2005 1990 2005 1990 2005 1990 2005 1990 2005 1990 2005

OECD Europe

OECD Pacific

US

&Canada China India

Mexico Brazil

South

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Services Transport Other

Households Manufacturing

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Gaz ziemny

Wydobycie, rynki, transport

37

This section highlights regional supply and demand balances for the years to 2015, based on data and analysis published in November 2007 in the IEA’s World Energy Outlook 2007. Price assumptions in that analysis were centred on oil prices at USD 60, with gas priced at around USD 7-8 per MBtu and coal at USD 60 per tonne, refl ecting the market outlook at the time the analysis commenced. Analysis for this year’s World Energy Outlook will be conducted with signifi cantly higher price assumptions, more refl ective of current energy prices as of May 2008, of USD 130 oil, gas at USD 10-12 per MBtu, and coal over USD 150 per tonne in some markets. This is likely to lead to differing projections, both in overall energy use and gas. The 2008 World Energy Outlook will be available in early November 2008.

World primary energy demand in the WEO 2007 Reference Scenario is projected to grow by 55% between 2005 and 2030, an average annual rate of 1.8%.

Demand reaches 17.7 billion tonnes of oil equivalent, compared with 11.4 billion toe in 2005. The pace of demand growth slows progressively over the projection period, from 2.3% per year in 2005-2015 to 1.4%

per year in 2015-2030. Demand grew by 1.8% per year over 1980-2005.

Global demand for natural gas grows by 2.6% per year from 2 854 bcm in 2005 to 3 689 bcm in 2015. As with oil, gas demand increases quickest in developing countries.

The biggest regional increase in absolute terms occurs in the Middle East, where gas resources are extensive and prices low.

North America and Europe nonetheless remain the leading gas consumers in

Natural Gas Market Review 2008 • Regional demand & supply balance to 2015

REGIONAL DEMAND AND SUPPLY BALANCE TO 2015

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38

2015, accounting for around 40% of world consumption, compared with just under half today.

New power stations, mostly using combined-cycle gas turbine technology, are projected to absorb over half of the increase in gas demand over the projection period. In many parts of the world, gas remains the preferred generating fuel for economic and environmental reasons. Gas- fi red generating plants are very effi cient at converting primary energy into electricity and are cheap to build, compared with coal- based and nuclear power technologies.

Gas is also favoured over coal and oil for its lower emissions, especially of carbon dioxide. However, the choice of fuel and technology for new power plants will hinge on the price of gas relative to other generating options.

Worldwide gas resources are more than suffi cient to meet projected demand to 2015 and beyond subject of course to adequate and timely investment. Gas production is projected to increase in all major regions except OECD Europe, where output from the North Sea is expected to decline. North American growth is expected to slow after 2015. As with demand, the Middle East sees the biggest increase in production in the period to 2015. Output also increases markedly in Africa and Latin America. Natural gas supplies will continue to come mainly from conventional sources, though coalbed methane and other non- conventional supplies are expected to play a growing role in some regions, notably North America. As with oil, projected gas- production trends generally refl ect the relative size of reserves. However, unlike oil, transporting gas over long distances is

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39

more costly, and production is also linked to proximity to the main consuming markets.

How major resource holders will respond to increasing demand, particularly the rate of investment, rapidly rising costs and development of more remote gas deposits is a matter of considerable uncertainty.

Although most regions continue to be supplied mainly with indigenously produced gas, the share of gas supply that is traded between regions grows from 13% in 2005 to 17% in 2015. All the regions that already import gas (on a net basis) become more import-dependent by 2015, both in terms of volume and, with the exception of OECD Pacifi c, the share of total consumption. Imports to OECD Europe increase most in absolute terms, from 234 bcm to 350 bcm in 2015. North America, which only recently started importing LNG

in signifi cant quantities, becomes a major importer. A signifi cant portion of the increase in global inter-regional exports over the period comes from the Middle East and Africa. Most of these additional exports go to OECD countries.

LNG accounts for about 84% of the increase in total inter-regional trade, with exports growing from 192 bcm in 2005 to approximately 400 bcm in 2015.

In OECD North America, inter-regional imports will be expected to come solely as LNG. OECD Europe will be supplied by both pipeline gas and LNG. As domestic production is expected to decrease, the largest growth of LNG imports is expected to be in Europe. In OECD Pacifi c, Australia is expected to expand its role as intra- regional LNG supplier, as well as an LNG supplier to China.

0 100 200 300 400 500 600 700 800 900 1 000

2005 2015 2005 2015 2005 2015

OECD Europe OECD North America OECD Pacific

Pipeline imports LNG imports

Regional production

bcm

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40 Natural Gas Market Review 2008 • Regional demand & supply balance to 2015

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Rynki regionalne - gaz ziemny U.S.A.

Zasoby gazu i główne rejony użytkowania

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42 Natural Gas Market Review 2008 • Investment in new supply projects

0 2 4 6 8 10 12 14 16

Average

‘98-'04

‘05 ‘06 ‘07 ‘08 ’09 ’10 Average

‘98-'04

‘05 ‘06 ‘07 ‘08 ’09 ’10

Investment (left axis) Add. Cap (right axis)

0 100 200 300 400 500 600 700

YearlyinvestmentsbillionUSD Capacityadditionsbcm/year

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The boundaries and names shown and the designations used on maps included in this publication do not imply official endorsement or acceptance by the IEA.

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MEXICO

UNITED STATES OF AMERICA Central

Western

Southwest

Southeast Northeast Km

0 200 400

Midwest

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1 2

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Rynki regionalne - gaz ziemny EU

136 Natural Gas Market Review 2008 • OECD countries and regions

Supply

The major EU gas producers are the United Kingdom and the Netherlands, producing 70% of EU gas output. Other signifi cant producers are Denmark, Romania, Germany and Italy producing almost all of the remainder.

EU gas production peaked in 1996, plateauing until around 2004. United Kingdom production peaked in 2000, production declining rather more rapidly than anticipated in recent years, so that 2007 output was around two-thirds of that in 2001. Recently, production falls in the United Kingdom have averaged between 8 and 10% per annum reducing gas output in 2007 to 76 bcm. This trend seems set to continue, with EU production dropping in line with its mature status; falling around 12% in 2005 – 2007, to the point where 2020 output is expected to be about 56%

of 2004 production.

Natural gas imports

Gas imports have been an important feature of Europe’s gas supply for some decades, fi rstly from Russia, via pipelines through Ukraine and Czech and Slovak Republics, and more recently Belarus and Poland. Pipeline imports arrived in southern Europe from Algeria in the early 1980s. Norway started exporting gas via pipeline in the 1970s, but has recently sharply raised volumes by around 70%

(or 35 bcm) between 2001 and 2007, to 85 bcm. In early 2008 exports rose by nearly 20% compared with the same period in 2007. LNG has become a more prominent import vector in recent years, notably in Spain. By 2005, the EU imported 57% of

gas consumption. Main import sources for gas supplies to Europe are Russia (24%

of consumption), Norway (15%) both by pipeline and Algeria (11%), by both pipeline and LNG. LNG imports were about 13% of total gas needs, with the major suppliers being Algeria, Libya, Qatar, and Nigeria.

Pipeline import routes to the EU are mainly from Russia directly and via Ukraine and Belarus, from Norway, from Algeria via Morocco and Tunisia, from Libya, and from Iran/Azerbaijan via Turkey.

The total annual entry capacity is about 375 bcm. The EU has 14 LNG terminals in operation with a total capacity of around 103 bcm. Gross import capacity is thus almost 480 bcm, with most of the unused capacity on the lines from Russia. This is probably suffi cient to meet import needs up to early into the next decade, at least on an annual basis. New supply projects are being built, notably pipelines from North Africa, and a signifi cant number of new or expanded LNG terminals, with further proposals being advanced (e.g.

Turkmenistan and Uzbekistan 1%

Other 8%

Norway 21%

Nigeria 4%

Algeria 18%

Egypt 2%

Libya 2%

Qatar 2%

Trinidad and Tobago 1%

Russia 41%

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137

new pipelines from Russia and the Caspian region and additional LNG capacity, notably in Northern Europe).

By 2015-2020, LNG imports could be between 120 - 140 bcm, more than double current levels. IEA analysis indicates that the demand for gas imports by pipeline could be as high as 400 – 420 bcm per year by around 2020. Norwegian exports then are likely to be around 120 bcm, although the resource base could probably supply more. Pipeline supplies from North Africa and Russia, plus other new sources, would therefore need to make up 280 - 300 bcm in 2020. In 2005, total imports from Russia, Algeria and Libya were respectively, 140 bcm, 37 bcm, and 5 bcm, for a total of 182 bcm. Gas demand projections are uncertain however, and it is possible that achieving the EU’s March 2007 energy policy commitments could

reduce projected volumes, if additional, for example renewable capacity, replaces natural gas.

Exports

Internal exports of gas within the EU total around 80 bcm, and are dominated by the Netherlands, accounting for nearly two thirds of the total. These can be expected to decline by the middle of the next decade. United Kingdom, Denmark and Germany account for almost all of the remainder, with the United Kingdom and Germany being net importers.

Outlook

Clearly the outlook is for gas to play a growing role in meeting EU energy needs, and for a growing relationship with the

Natural Gas Market Review 2008 • OECD countries and regions

-30 -20 -10 0 10 20 30 40 50 60 70 80

NLD

DNKEST SWE SVN LUX LVA LTU BGR GRC IRL PRT FIN ROU SVK AUT CZE POL HUN GBR

BEL ESP FRA ITA DEU

2000 2006

1990

Mtoe

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55

Trans-Caspian issues

A summit meeting of Caspian leaders in Tehran in October 2007 showed little sign of consensus on issues of oil and gas transportation or on the legal status of the Caspian Sea. Instead, the development with most potential implications for trans- Caspian energy trade was the improvement in relations between Turkmenistan and Azerbaijan.

After President Berdymukhammedov came to power in Turkmenistan in February 2007, formal inter-governmental contacts were resumed in the autumn of 2007 after a

break of seven years, and Turkmenistan announced in spring 2008 a decision to re- open an Embassy in Azerbaijan. The most visible sign of the warming of relations was the visit of President Berdymukhammedov to Baku in May 2008.

The relationship between Turkmenistan and Azerbaijan is a pivotal one for the prospects of trans-Caspian gas trade, whether this is in the form of Turkmen offshore gas being landed in Azerbaijan, trans-Caspian gas shipments (possibly as CNG) or, in the medium-term, a fully fl edged trans-Caspian pipeline feeding into the Azerbaijan gas pipeline

Natural Gas Market Review 2008 • Investment in new supply projects

France

Spain Portugal

Italy

Algeria Morocco

Tunisia

Russia Finland

Sweden

Greece Alb.

Bulgaria Romania Bos. &

Herz.

Belg. Germany Poland

Austria Hungary Switz.

Lux.

Serbia

FYROM Mold.

Slovakia Czech

Rep.

Russia

Ukraine Belarus

Slov.

Croatia Ireland

UK

Iraq Iran

Georgia Azer.

Arm.

Lithuania Latvia

Estonia

Turkey

Syria Norway

113 bcm

151bcm

86 bcm

7bcm

Denmark The Neth.

Norway to OECD Europe

Atlantic LNG

Russia 223bcm

85bcm 156bcm

Russia to OECD Europe

and Balkans

18 bcm Used: 6 bcm 52 bcm Iran 51

bcm 58

bcm

42 Used: bcm

29 bcm

19 32 bcm

bcm

North Africa pipeline to OECD Europe Mediterranean

LNG

Kazakhstan

Uzbekistan

Turkmenistan Used:

27bcm 46bcm

Used capacity Existing capacity Projected capacity Existing LNG terminal

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58 Natural Gas Market Review 2008 • Investment in new supply projects

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Nordstream

Gazoprojekt

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Gaz ziemny

LNG - Liquified Natural Gas

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Gazoprojekt

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66

Refl ecting its traditional emphasis on gas, the company’s gas and power unit has been successful in establishing its integrated value chain to the company’s gas reserves, which are developed by its exploration and production division.

In addition to its stakes in the liquefaction projects mentioned in the LNG section and a one-sixth holding in the Australia’s

North West Shelf (NWS) project, the company has stakes in four LNG liquefaction trains under construction:

two trains on Sakhalin Island in Russia;

one big train in Qatar (Qatargas IV); and the fi fth train of the North West Shelf (NWS) project. It also has an indirect stake in the Pluto project in Australia through a 34% holding in Woodside (itself likely to emerge as a major LNG producer by

Natural Gas Market Review 2008 • Investment in new supply projects

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84

that the non-OECD market’s ability and willingness to import LNG is growing.

A signifi cant number of new countries will enter LNG markets as buyers and sellers in the new few years. Details are set out in Table 20.

Pricing outlook

As demand continues to rise and new liquefaction plants are more expensive to build, and often run over budget and schedule, the LNG market looks set to remain tight in coming years, not withstanding the massive increase in

capacity, particularly to 2009. However, long-term prices may not continue rising if more supply emerges around the turn of the decade. To the extent they can, buyers are likely to resist long-term commitments at higher prices. As geographically fl exible and uncommitted LNG exporting capacity expands and correspondingly large numbers of ships are delivered, the proportion of short-term cargoes will increase from levels around 10% early in the decade, to current levels of 20%, towards 30% early next decade. Pricing for those cargoes seems likely to be increasingly decoupled from that of long-term transactions and increasingly on a global basis.

Natural Gas Market Review 2008 • Liquefied natural gas

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]-2-*&3'(("45&<78*&3'(!$V4 :8EK8=+*&3'((C45&G-7B&3'(!(45 G8;B8&T-U&FB+*-8&3'(!NV4

!"#$%&'( <$=*&%+9:6)*46%9>+$*:6+*?$(?946+*6+*&9%*)&+$*)(6@AB6&%)49:5

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^^a>M7+.&b&G71.B9+*0&91B*,7+-?&UK+9K&U1B=.&M-&;1?+,+1*-.&,1&71B,+*-=>&?B;;=>&M1,K&,K-&R,=8*,+9&8*.&G89+_+9&7-0+1*&WTF&287E-,?`

:1B79-c&<ZR`

LNG w Polsce Świnoujście

Terminal o przepustowości 2.5 bcm/year (10

⁹

m

³

), projekt zakontraktowany u SNC Lavalin (Kanada) za USD 10.6 milionów.

9 m-cy projektowania,

uruchomienie 2012 lub później obecnie ponad 90% gazu z Rosji

prawdopodobny dostawca LNG to Algieria i Katar

37

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Rynki narodowe - gaz ziemny Polska

40

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42 Saturday, March 23, 2013

(15)

GazoprojektGazoprojekt

43

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Rynki narodowe - gaz ziemny Niemcy

Włochy Chiny Indie

49

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145 Natural Gas Market Review 2008 • OECD countries and regions

G E R M A N Y

Amsterdam Berlin

Prague

Bern Lux. City BELGIUM

THE NETHERLANDS

DENMARK

P O L A N D

C Z E C H R E P U B L I C

A U S T R I A F R A N C E

S W I T Z E R L A N D L U X .

LIECH.

Oberkappel

Burghausen Waidhaus

Olbernhau Deutschneudorf Eynatten

Bocholtz Emden

Dornum

Mallnow Ellund

Winterswijk Zevenaar

Bunde

Bonn

0 Miles 100

100 0 Km

Main gas pipeline

0.34

1.17 1.15

1.24

1.302.00 Low caloric High caloric

1.50 1.25

0.73 1.53 1.38 1.71

3.7

0.42

0.42 3.00

Import entry point - maximum flow rate (million m /h)³

!"#$% !"#$%&'(%)'*$+,#-'"&-#.'+,*&-)

!"#$%&'()*+(,$*-+./++/"-(0#$"1&2()*+(3-4$*+5$#%5#$&(0#$"1&2(6%5"7&$(899:2(%".1*-;(/-4"$.*5/"-2(30<(*-*=;+/+>

?"5&'(@*A/.#.(4="B($*5&(*5(0.C&-(&D#*=+(5"5*=(.*A/.#.(4="B($*5&(*5(5E&(&-5$;(./-#+(%*1*%/5/&+(C&+5/-&C(4"$(5E&(?&5E&$=*-C+(*+(

1&$(F(G*-#*$;(899H>(

150

Competition and liberalisation issues

Since the beginning of European liberalisation the Italian authorities have undertaken a series of compulsory changes to the structure of the Italian gas market in order to ensure fair access to pipelines and effective competition in supply. Notably, these measures included very precise and progressive gas release programs, and ownership and market share limitations for the incumbents. However, the dominant position of Eni is still an issue for the regulatory authorities and in 2007 the European Commission commenced

Natural Gas Market Review 2008 • OECD countries and regions

antitrust proceedings against the Italian gas incumbent in relation to the potential exclusion of new entrants in the Italian market. Eni is being accused of capacity hoarding and strategic underinvestment on the Italian gas transmission network, intending market foreclosure which would threaten not only development of competition but also security of supply for Italian customers.

Despite several measures aiming to restrain Eni’s dominant position in the Italian market, the incumbent operator sells nearly half of all end-user gas. In the midstream sector of the market, Snam

Zaule -8 Monfalcone -8

Rovigo -8 Panigaglia -3.5

Panigaglia expansion, under dev.

-4.5

Livorno -3.75 Rosignano -8

Gioia Tauro -12

Porto Empedocle -

8

Greenstream Libya +3 Taranto -

8

Priolo -8 Brindisi -8 Le Marche -5-10 TAG pipeline

Russia TENP pipeline

Netherlands-Norway

ITGI pipeline TAP

Transmed Algeria GALSI pipeline

21 36

32 8

8

10-20 8

Possible import capacity: >230bcm/y Existing supply capacity (pipeline and LNG): 101 Under development: 98 - 113

Under construction: 19.75

LNG terminal

!"#$% !"#$%&'()*$+"'"+%*,$')(-.+*#$%/$0*"1,

!"#$%&'()*+,(-./.01$2("3()/4#01$2,(%"567/2(0"#$%&08 9"1&'(7::(/#5;&$0(&<6$&00&4(./(;%58

182

under current market conditions, but government policy aimed at diversifying the electricity mix and reducing local pollution should increase the share of gas in some regions and in particular along the Yangtze River Delta region. By the start of 2008, China had 69 gas-fi red generators operating some 17 500 MW of capacity. The bulk of this capacity, 85%, is to be found in coastal areas and includes the cities of Guangdong, Fujian, Zhejiang and Hainan. Most of the gas consumed in the region is sourced domestically, either from inland fi elds or from offshore resources. The exception to this is Guangdong, which sources much of its gas from the Dapeng LNG terminal on the eastern side of the Pearl River delta in southern coastal China.

Additional LNG infrastructure is being build to meet the immediate shortfall as demand for gas continues to outstrip domestic supply. China received its fi rst LNG shipments to the Dapeng terminal in 2006 and another terminal opened in Fujian province in April 2008. Construction of a further two terminals near Shanghai and Dalian, Liaoning, in the northeast, is underway. Some engineering work is also in progress at the planned Rudong terminal in Jiangsu. Growth in gas-fi red generation will be strongly linked to additional import capacity and the price of imported LNG. Additionally, growth in gas-fi red generation will to some extent be linked to electricity price reform. Some generators in the Guangdong Province rely on government subsidies to maintain output as there is a disconnection

Natural Gas Market Review 2008 • Non-OECD countries and producing regions

MONGOLIA

C H I N A KAZAKHSTAN

TAJIKISTAN

INDIA

MYANMAR LAOS

NEPALBHUTAN

BANG.

RUSSIA

West to East pipeline

RUSSIA

JAPAN N. KOREA

KOREA Beijing

Shanghai

Fujian

Guangdong

0 400

0 600

Miles Km Gas pipeline Gas pipeline planned LNG terminal LNG terminal planned

!"#$%

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!"#$%&$%'()%*&+%,&#$-)%,')(.'()/

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190

Southeast Asia

Traditionally, the demand for gas in Southeast Asia was satisfi ed by gas producing countries within the region.

Recently, demand for energy has accelerated; the challenge will be to ensure that gas supply meets this increasing demand, given that the alternative is likely to be oil products.

Indonesia, the biggest LNG exporter in the region, is experiencing falling LNG production. Other producing countries, such as Malaysia and Brunei, are expected to offer modest prospects of additional volumes. Issues of resource nationalisation also arise regularly within the region.

Another obstacle to the development of

oil and gas reserves is recurring border disputes i.e. the Brunei and Malaysia dispute, overlapping claims areas between Thailand and Cambodia in the Gulf of Thailand, and various countries’ claims on the Spratly Islands. The exploration and development at these areas could be intensifi ed if the affected countries could resolve these disputes, and allow for example joint-sharing of benefi ts. An example of this is the joint development area (JDA) model that was successfully adopted by Malaysia and Thailand for Block A-18 in the Gulf of Thailand, which started to produce gas in 2005, following a similar example of the Bayu Undan joint venture project in the Joint Petroleum Development Area (JPDA) between East Timor and Australia. That venture started

New Delhi

CHINA

THAILAND MYANMAR LAOS

BANGLADESH BHUTAN NEPAL

I N D I A PAKISTAN

IRAN

OMAN

SRI LANKA Amritsar

Delhi

Kolkata Cuttack

Kakinada

Chennai Bhopal

Hyderabad

Bangaluru Jamnagar

Jaipur

Patna

Trivandrum Kochi Mumbai

Hazira Dahej

Dabhol

0 500

Miles Km

Gas pipeline

Gas pipeline planned or under const.

LNG import terminal LNG import terminal under const.

!"#$% !"#$%"&'%(&$")*%(+*,-+,*.

!"#$%&'()&*$"+&#,(-%".",/0*(1.2(3-45

Rynki regionalne - gaz ziemny Azja Południowo-Wschodnia Ameryka Południowa

Afryka

191

LPG and condensate production in 2004, before exporting LNG from Darwin, Australia in 2006.

Overall, and despite these obstacles, there are reasonable prospects for untapped gas resources in Southeast Asia, with new players emerging in the region’s gas market like Papua New Guinea and East Timor.

Brunei Darussalam

Brunei, which was a pioneer in the development of liquefaction plant in Western Pacifi c, is currently the world’s tenth largest LNG producer; oil and gas exports account for more than half of its GDP. The majority of its gas is exported under long- term contracts; 90% of its LNG goes to Japan and the remainder is sold under long- term contract to Korea’s Kogas. In addition

to export, gas is consumed domestically in electricity production, petrochemicals and other energy intensive industries. Close to 100% of electricity is gas-fi red.

Brunei is intensifying its efforts in the exploration and development of new fi elds to enable it to extend its contracts with Japan and South Korea subsequent to the expiry of the current contacts in 2013.

The recent Bubut offshore gas discovery, 15 km from Brunei LNG (BLNG) by Brunei Shell Petroleum Company Sdn Bhd, a joint venture between Shell and Brunei’s government, offers hope for possible contract extension beyond 2013. Efforts are also being made in rejuvenating its 36-year old LNG facility. This project, which commenced in 2004, is expected to be completed in 2010 extending the plant life to 60 years.

Bontang

Tangguh

West Java

Lumut Bintulu MLNG Arun

East Java

Masela Jurong Isl.

Mariveles LNG (Baatan)

MALAYSIA VIETNAM

PHILIPPINES

EAST TIMOR SINGAPORE

CAMBODIA

BRUNEI THAILAND

Kalimantan Senipah

Surabaya Plaju Sungiasalak Dumai Medan Map Ta Phut

Krabi Khanom

Pasuruan Natuna

Palawan Ho Chi Minh

Mindanao Luzon

Phnom Penh Yangon

Bandar Seri Begawan

Manila

Dili Kuala Lumpur

Bangkok

Sumatra

Java

LombokBali Sumbawa Flores

Sulawesi Seram Papua

I N D O N E S I A

Port Moresby PAPUA NEW GUINEA Jakarta

Existing gas pipeline

Planned LNG import terminal Planned LNG export plant Planned or under construction gas pipeline Gas production area LNG export plant

0 500

Miles Km

!"#$% !"#$%&'($)*(+',)-'()+,./'($/#0$#/&

!"#$%&'()&*$"+&#,(-%".",/0*(1.2(3-45

55

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202 Natural Gas Market Review 2008 • Non-OECD countries and producing regions

With this volume, the region would remain a niche from the perspective of the global LNG market, but South American countries will become more exposed to international price levels.

Argentina

The gas shortages that started in 2004 in Argentina are becoming even more

pronounced, particularly during hot summers or cold winters. Residential tariffs remain frozen at 2001 prices, thereby creating a strong disincentive to save energy and encouraging rapid demand growth. These artifi cially low prices have further hampered investment in new production capacity and new transmission facilities. While Argentina pays USD 7 per MBtu for natural gas from Mexico

27%

Colombia 22%

Peru 12%

Bolivia 27%

Brazil 9%

Argentina 52%

Trinidad 87%

Venezuela 39%

Chile 26%

!"#$%& !"#$%&'(&)#*&+,&-'-#.&/$+0#$1&%,%$)1&*2//.1&+,&3%,-$#.&#,4&!'2-"&50%$+6#&#,4&7%8+6'

!"#$%&'()*+,

Udział gazu w całkowitych

dostawach energii

211 Natural Gas Market Review 2008 • Non-OECD countries and producing regions

B R A Z I L

URUGUAY

ARGENTINA PERU

CHILE ECUADOR

PARAGUAY BOLIVIA COLOMBIA

VENEZUELA GUYANA

BARBADOS

COS. RICAPAN.

EL SAL.NIC.

HONDURAS BELIZE MEXICO

GUA. GUADELOUPE (FR.)

TRINIDAD & TOBAGO

SURINAMEFRENCH GUYANA

Manaus Coari

Porto Velho

Fortaleza Natal Recife Aracaju Salvador Mataripe

Sao Mateus Vitoria Brasilia Paramaribo

Cayenne Georgetown Caracas

Port of Spain

Asuncion La Paz

Santiago Montevideo

Lima Quito

Bogota

Campos Basin Campos Rio Cuiaba

Corumba

Rio Grande Sao Fransisco do Sul Peru LNG

Pucallpa Shushufindi Cali

Santander Apiay Medelin

Ilo Tocopilla

Paposo Antofagasta Mejillones

Valparaiso

Conception/Talcahuano

Ushuaia San Julian Caleta OliviaCaleta Cordova

Punta Arenas Viedma

Bahia BlancaMar del Plata La Mora Cordoba Catamarca

La Rioja Uruguaiana Porto Alegre

Buenos Aires San Lorenzo

Neuquen Potosi

Salta

Betim

Sao Paulo Atlantic LNG Gran Mariscal

Quintero

Guanabara Bay Pecém Cartagena

Gas pipeline

Gas fields LNG export plant

LNG import terminal planned LNG export plant planned Gas pipeline planned or under const.

0 1 000

Miles Km

!"#$%% !"#$%&'()*+,-.&/-0&+.1*-0$*#,$#*)

!"#$%&'()&*$"+&#,(-%".",/0*(1.2(3-45

Infrastruktura gazowa w

Ameryce Południowej

Natural Gas Market Review 2008 • Non-OECD countries and producing regions 213

MALI NIGER

NIGERIA

CAMEROON CENTRAL AFRICAN REPUBLIC MAURITANIA

MOROCCO

WESTERN

SAHARA ALGERIA

TUNISIA

SENEGAL

GUINEA IVORY COAST

GHANA TOGO

SAO TOME & PRINCIPE EQUA. GUINEA

DEMOCRATIC REP.

OF CONGO RWANDA

TANZANIA

MALAWI

LESOTHO SWAZILAND ZAMBIA

ZIMBAWE NAMIBIA

MOZAMBIQUE MADAGASCAR BOTSWANA

SOUTH AFRICA Cape Town

Maseru Windhoek

Harare Lilongwe

Antananarivo Comoro Cape

Verde Canary Isl. (Spain) Madeira (Port.)

Lusaka Dodoma Luanda

Kinshasa

Bujumbura Nairobi

Mombasa Kampala

Addis Ababa Djibouti

Mogadishu Karthoum

Asmara San’a Riyadh Baghdad

Cairo

Bangui Ndjamena Abuja Bamako

Monrovia Freetown Conakry Dakar

Nouakchott Rabat

Algiers

Tripoli

Bissau Banjul

Yamoussoukrou Abidjan

Kaduna

Pointe Noire Malongo Quinfuquena

Qena

Ouagadougou Niamey

Libreville Yaounde Lome

Kigali Brazzaville

Pretoria Gaborone

Maputo Mbabane

Mossel Bay Alexander Bay

Richard’s Bay Sasolburg Johannesburg

Durban BURUNDI CABINDA

BENIN

GUINEA-BISSAU

BURKINA FASO

SIERRA LEONE

DJIBOUTI Y JORDAN

SYRIA IRAQ

KUWAIT SAUDI

ARABIA

LIBERIA THE GAMBIA

CHAD LIBYA

SUDAN ETHIOPIA

SOMALIA UGANDA CONGO

ANGOLA GABON

KENYA ERITREA EGYPT Sahara Desert

In Salah In Amenas Hassi Messaoud

Accra P. Novo

NLNG (Bonny Isl.)

Marsa el Brega

Arzew Skikda ELNG

T1 & T2Damietta LNG

Brass LNG OK LNG

Byoko Isl.

0 1 000

Miles Km

Existing gas pipeline

Planned LNG import terminal Under const. or planned LNG export plant Planned or under construction gas pipeline Gas production area

LNG export plant Gas field

!"#$%& !"#$%&'()&*($'"#&*+#,%+,#-

!"#$%&'()&*$"+&#,(-%".",/0*(1.2(3-45