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8/6/2019 Regional Market Outlook Energy Studies Institute
1/17
Dr. Tilak K. DoshiChief Economist & Principal Fellow
Chew Wee Kian Alvin
Energy Analyst
Examining Regional Market Outlooks and
Developments
12th October 2010
Gas Asia Conference 2010,
Kuala Lumpur, Malaysia
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Primary Energy Demand by Fuel (MTOE)Primary Energy Demand by Fuel (MTOE)
Despite increasing emphasis on renewables and other non-fossil sources ofenergy, coal, oil and natural gas occupy a predominant share of fuel sourcesin the foreseeable future (81.5% in 2007; 80.1% in 2030).
CAGR
1980 2007 2030 1980-2007 2007-2030 2007 2030
Coal 1,792 3,184 4,887 2.2% 1.9% 26.5% 29.1%
2
, , , . . . .
Gas 1,234 2,512 3,561 2.7% 1.5% 20.9% 21.2%Nuclear 186 709 956 5.1% 1.3% 5.9% 5.7%
Hydro 148 265 402 2.2% 1.8% 2.2% 2.4%
Biomass 749 1,176 1,604 1.7% 1.4% 9.8% 9.6%
Renewables 12 74 370 7.0% 7.3% 0.6% 2.2%
Total 7,228 12,013 16,790 1.9% 1.5% - -
Source: IEA World Energy Outlook 2009
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Primary Energy Demand by Region (MTOE)Primary Energy Demand by Region (MTOE)
Asia (including China and India) and the Middle East have the most rapidenergy demand growth
CAGR Share
1980 2007 2030 1980-2007 2007-2030 2007 2030
OECD 4,050 5,496 5,811 1.1% 0.2% 45.8% 34.6%
North America 2092 2793 2974 1.1% 0.3% 23.2% 17.7%
United States 1,802 2,337 2,396 1.0% 0.1% 19.5% 14.3%
3
Europe 1,493 1,826 1,894 0.7% 0.2% 15.2% 11.3%
Non-OECD 3,003 6,187 10,529 2.7% 2.3% 51.5% 62.7%
Asia 1,068 3,346 6,456 4.3% 2.9% 27.9% 38.5%
China 603 1,970 3,827 4.5% 2.9% 16.4% 22.8%
India 207 595 1,287 4.0% 3.4% 5.0% 7.7%
Middle East 128 546 1,030 5.5% 2.8% 4.5% 6.1%
Others 1,808 2,295 3,043 0.9% 2.3% 19.1% 18.1%
World 7,228 12,013 16,790 1.9% 1.5% - -
Source: IEA World Energy Outlook 2009
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Primary Natural Gas Demand by Region (bcm)Primary Natural Gas Demand by Region (bcm)
CAGR Share
1980 2007 2030 1980-2007 2007-2030 2007 2030OECD 958 1,527 1,761 1.7% 0.6% 50.1% 40.8%
North America 659 813 892 0.8% 0.4% 26.7% 20.7%
United States 581 655 649 0.4% 0.0% 21.5% 15.0%
Europe 264 544 651 2.7% 0.8% 17.8% 15.1%
Asia and the Middle East also account for the fastest growth in natural gasdemand; natural gas will increase in importance in these countries
4
Japan 25 100 111 5.3% 0.4% 3.3% 2.6%Non-OECD 559 1,523 2,553 3.8% 2.3% 50.0% 59.2%
Asia 36 319 748 8.4% 3.8% 10.5% 17.3%
China 14 73 242 6.3% 5.3% 2.4% 5.6%
India 1 39 132 14.5% 5.4% 1.3% 3.1%
Middle East 36 294 602 8.1% 3.2% 9.6% 14.0%
Others 488 910 1203 2.3% 4.0% 29.8% 27.9%World 1,517 3,049 4,313 2.6% 1.5% - -
Source: IEA World Energy Outlook 2009
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LNG Liquefaction Capacity Outlook
500
600
700
800
Metres
World liquefaction capacity sharply increases, led by Qatar, Australia andWest Africa, from about 390 bcm at end-2009 to 460 bcm by 2015 and 600bcm by 2020
0
100
200
300
400
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026 2028 2030
North America Europe Asia Asia PacificLatin America FSU Africa Middle East
BillionCu
bic
xls 40749 WGMO Sec 4 Source: Nexant forecasts
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Natural Gas Proved Reserves (end 2009)Natural Gas Proved Reserves (end 2009)
Share R/P
tcf of total Ratio (yrs)
North America 323 4.9% 11.3
US 245 3.7% 11.7S. & Cent. America 285 4.3% 53.2
Venezuela 200 3% >100Europe & Eurasia 2,228 33.7% 64.8
Russian Federation 1,567 23.7% 84.1
Middle East and FSU dominate conventional reserves
, .
Iran 1,046 15.8% >100Qatar 896 13.5% >100
Africa 521 7.9% 72.4Algeria 159 2.4% 55.3
Nigeria 185 2.8% >100
Asia Pacific 574 8.7% 37
Australia 109 1.6% 72.7Indonesia 113 1.7% 44.3
Malaysia 84 1.3% 38
World 6,621 62.8
6
Source: BP Statistical Review of World Energy 2010
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Natural Gas Proved Reserves (end 2009)Natural Gas Proved Reserves (end 2009)
(with US Shale Gas estimate)(with US Shale Gas estimate)
Share R/P
tcf of total Ratio (yrs)
North America 323 4.9% 11.3
US 245 3.7% 11.7S. & Cent. America 285 4.3% 53.2
Venezuela 200 3% >100Europe & Eurasia 2,228 33.7% 64.8
Russian Federation 1,567 23.7% 84.1
tcfR/PRatio (yrs)
Including shale gas
>3,000 >100
China and Australiaexpected to have
e ast , . >
Iran 1,046 15.8% >100Qatar 896 13.5% >100
Africa 521 7.9% 72.4Algeria 159 2.4% 55.3
Nigeria 185 2.8% >100
Asia Pacific 574 8.7% 37
Australia 109 1.6% 72.7Indonesia 113 1.7% 44.3
Malaysia 84 1.3% 38
World 6,621 62.8
7
Source: BP Statistical Review of World Energy 2010, IHS/CERA shale gas estimates 2010
US. Exxon, Chevron, Shell
and ConocoPhilipshave acquired shalegas prospects in
Poland, Sweden andGermany
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USGS Hydrocarbon Resource Estimates(Conventional v. unconventional)
Conventional hydrocarbons: dominating role of the Middle East OPEC dueto the geographical distribution
Unconventional hydrocarbons: are subject to great uncertainty indevelopment costs (e.g. Canadian tar sands)
However, North American shale gas is game changer with global impacts(with China, Europe, India and Australia all also having potential shale gasand CBM availability)
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EIA US Gas Supply Forecasts
20
25
trillion cubic feet
Shale gas
EIA forecasts of just 2 years ago might be conservativeshale gas couldconstitute half of all US gas supply by some estimates
0
5
10
15
1990 2000 2008 2015 2025 2035
Coalbed methane
Other lower 48 onshore(including tight gas)
Lower 48 offshore
Source: EIA, 2009
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Gas ProductionGas Production
Long Run Marginal Cost ($/mmbtu)Long Run Marginal Cost ($/mmbtu)
4
5
6
Indonesia
South
USA
Offshore
-
Indonesia
North
Sumatra
$2.35
Barnett
Shale
$3.4
Appalachian
coal seam
$4.86
Piceance
Tight
$6.8US shale gas breakeven prices at $3 - $5/mmBTU,according to Shell (FT, Oct 2nd, 2010)
1010
0
1
2
3
LRMC
Nigeria
Associated$0.1
Qatar North Field
$0.2
USA
12000
ft
$0.29
Algeria
$0.5
UAE
$0.55
China
$0.8
Australia East
Coast
$0.85
Trinidad and
Tobago
$1.25
Qatar AlKhaleej
$1.3
Brunei
$1.5
Sumatra
and Java$1.6
Russia
Shtokman
and Yamal
$1.7
$1.73
Indonesia
EastKalimantan
and Sulawesi
$2
Indonesia
Irian Jaya
$2.75
Pinedale
Tight
$3.5
WoodfordShale
$3.89
Source : Nexant, Energy Studies Institute
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Natural Gas Prices ($/MMBTU)
12
14
16
18
Japan Contract
Financial crisis and recession in 2008 led to steep fall-off in prices, with Japanspot LNG prices diving from $16/mmbtu peaks to below contract prices
0
2
4
6
8
10
2004 2005 2006 2007 2008 2009 2010*
Japan Spot
HH
NBP
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LNG Pricing Modes
No Price1%
Not Known
0.3%
Regulation BC
23%
Oil Price
Escalation
22%
In scenarios of global LNG surplus, price link to oil prices will be underpressure and spot LNG prices will diverge from oil-indexed higher pricedcontracted LNG flows
Bilateral
Monopoly
8%
Regulation SP
11%
Regulation
COS
3% Netback1%
Gas-on-Gas
Competition
31%
xls 40749 WGMO Sec 4
Source: Nexant estimates
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LNG Importers: New Players and Routes
Importing CountriesNumberYear
+India, China
+Turkey, Greece, Portugal, UK
202008
Japan, South Korea, Taiwan,
Belgium, France, Spain, Italy,
US
81998
+UAE, Singapore, Thailand?, HK?, Indonesia?,Pakistan?
+Netherlands, Germany, Poland?, Cyprus?
292015
+Puerto Rico, D. R., Mexico, Argentina, Brazil
Source: Deutche Bank, 2008
By 2007:84 country-to-country trades (+15 over 2006)264 sea transportation routes (+68 over 2006)
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Impacts of US Gas Shale Supply Shock
Indigenous natural gas supplies reduce the need for LNG imports into NorthAmerica which become a matter of choice rather than necessity.
Sempra, Cheniere and Freeport LNG have asked for FERC permission toturn their US import terminals into export terminals.
Huge Qatar planned supply to U.S. now likely to look for new markets,
New technologies to extract gas from shale rock have altered the U.S. energyoutlook for the next 100 years(Tony Hayward, BP, 2010)
.
Russian LNG projects previously targeting U.S. markets will also most likelylook to Asian markets.
The end result will be a pressure on natural gas prices, already weak sincetheir peaks in 2008.
Asian importers have an option value in sourcing larger shares of LNG
imports under spot or short term contracts given the outlook for softer spotLNG market for the medium term
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China Gas Infrastructure
RUSSIA
KAZAKHSTAN
China is said to have the second largest deposits of shale gas, after theUS; together with potential pipeline gas from Russia and Myanmar makesChinas options for gas supply far more competitive
Existing Import Terminals
Planned Import Terminals
Existing Pipelines
Planned Pipelines
CHINA
MYANMAR
PP: 40749 WGMO Asia Pacific Sec_5
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Levelized Costs of Electricity (2008)Levelized Costs of Electricity (2008)
Nuclear CCGT
SC/USC
Coal
Coal with
90% CCS
Onshore
Wind Solar PV
Diesel
Genset
Capacity (MW) 1,400 480 750 474 45 1 1
Investment Cost (S/kW)* 4,102 1,609 2,133 3,838 2,349 6,006 187
Natural gas will likely be used as an interim transition fuel in a carbon-constrained future, as CCGT remains among the most efficient technologiesfor power generation
16
O&M (cents kWh) 1.5 0.4 0.6 1.4 2.2 3 1.5
Fuel Cost (cents/KWh) 0.9 6.1 1.8 1.3 0 0 40.4
Load Factor (%) 85% 85% 85% 85% 26% 13% 85%
Lead Time (years) 7 2 4 4 1 1 1
Expected lifetime (years) 60 30 40 40 25 25 7
LCOE (cents/kWh) @ WACC=5% 5.9 7.5 4.1 5.9 9.7 41.1 42.3
LCOE (cents/kWh) @ WACC=10% 9.9 8.2 8.2 8.7 13.7 61.7 42.3
Carbon Cost at $60/ton
LCOE (cents/kWh) @ WACC=5% 5.9 9.6 9.6 6.5 9.7 41.1 46.8
LCOE (cents/kWh) @ WACC=10% 9.9 10.3 10.3 9.3 13.7 61.7 46.8
Sources: IEA Projected Cost of Generating Electricity, 2010; Energy Studies Institute calculations for diesel genset
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Thank You!Thank You!
17