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TRANSCRIPT
Changing Trends in World LNG Market and Cooperation to Improve Asian Gas market
국제LNG 시장의변화흐름과아시아가스시장개선 협력
2014. 11. 14
Hyun Jae Doh
KEEI-KPMG 에너지리더과정
Contents�
I. World LNG Market – Growth and Changing Trends
II. Shale Boom and North American LNG Export Potentials
III. Asian Premium and Cooperation to Improve Asian Gas Market
Contents�
I. World LNG Market – Growth and Changing Trends
II. Shale Boom and North American LNG Export Potentials
III. Asian Premium and Cooperation to Improve Asian Gas Market
KEEI- 3 -
Global Natural Gas Overview (2013)
Natural Gas Consumption: 3,348 Bcm
- Pipeline imports : 710.6 Bcm (21%), LNG imports : 325.3 Bcm (10%)
Source: IGU(2014)
Natural Gas 23.7%, Oil 32.9%, Coal 30.1% 32.9% 30.1%23.7%
6.7% 4.4% 2.2%
Oil Coal Natural Gas Hydro Nuclear Renewables
(2013)
Source: BP(2014)
Share in World Primary Energy ConsumptionShare in World Primary Energy Consumption
LNG Trade in Global SupplyLNG Trade in Global Supply
KEEI- 4 -
Natural Gas Consumption Share and Trade Flow
▶ North America: Prices linked to Henry Hub (US 22.2%, Canada 3.1%, Mexico 2.5%)
▶ Asia: Oil-linked pricing (China 4.8%, Japan 3.5%, Korea 1.6%, Thailand 1.6%, India 1.5%, Taiwan 0.5%)
▶ W. Europe: Prices linked to alternative fuels (Germany 2.5%, UK 2.2%, Italy 1.9%, Turkey 1.4%,
France 1.3%, Netherlands 1.1%, Spain 0.9%)
▶ FSU (Russia 12.3%, Uzbekistan 1.3%, Ukraine 1.3%)▶ ME (Iran 4.8%, Saudi 3.6%, UAE 2.0%, Qatar 0.8%)
▶ S. America (Argentina 1.4%, Brazil 1.1%, Venezuela 0.9%) ▶ Africa (Egypt 1.5%, Algeria 1.0%)
Source: BP(2014)
KEEI- 5 -
Global LNG Markets: Asia, Europe, North America- LNG share in gas trade expanding: 25.8%(2002) → 31.4%(2013)- Emerging New Markets: Latin America, Middle East, Southeast Asia
Major Trade Flows: Intra Pacific(~ 1/3), Middle East-Pacific(~ 1/3)- Middle East-Atlantic(13%), Intra-Atlantic(8.3%), Atlantic-Pacific(7.8%)
Sources: BP(2014), IGU
LNG Trade Flows
Source: IGU(2014)
< Interregional LNG Trade >
KEEI- 6 -
Global LNG Trade : 236.8 Mt- Non long-term trade: 77.3 Mt (33% of total trade) (GIIGNL: spot & ST trade - 65 Mt, 27% of total trade)
(Demand) Asia accounts for 74.7% of global LNG demand (176.98 Mt)- Europe 14.2%(33.74 Mt), North America 3.6%, Latin America 6.1%, Middle East 1.3%- 104 LNG receiving terminals(total capacity of 721 Mtpa) – 29 importing countries
(Supply) 41% of global LNG trade supplied by the Middle East- Asia Pacific 30%, Africa 15%, Latin America 9%, Russia 5%, Europe 2%- 86 liquefaction trains (total capacity of 290.7 Mtpa) – 17 exporting countries
State of LNG Industry in 2013
Source: GIIGNL(2014)
< 2013 LNG Imports change over 2012 >
KEEI- 7 -
Global LNG Trade- Reached peak of 241.5 Mt in 2011, 236.8 Mt in 2013- Growth in volume(2000~2012 CAGR 7.5%), # of exporters, # of importers
Source: IGU(2014)
Changing Trends in LNG Industry
KEEI- 8 -
Source: IGU(2014)
No. of countries 1990 2002 2010 2013 2020 est.
LNG Exporters 8 12 18 17 ~25
LNG Importers 9 12 24 29 ~40
Source: Ju(2014), GIIGNL(2014)
Changing Trends in LNG Industry
KEEI- 9 -
Changing Trends in LNG Industry
Source: IGU(2014)
Non Long-term trade: 77.3 Mt traded on a spot or short-term basis (33% of total LNG trade)(GIIGNL: spot & ST trade - 65 Mt, 27% of total trade)
- Until 2000, less than 5% of volume traded → in 2005, 8% → in 2007~2010, 17~20% Ø growth in LNG contract with destination flexibility Ø increase in # of exporters and importersØ disparity in regional prices → arbitrage
Contents�
I. World LNG Market – Growth and Changing Trends
II. Shale Boom and North American LNG Export Potentials
III. Asian Premium and Cooperation to Improve Asian Gas Market
KEEI- 12 -
9 LNG projects with a total capacity of 10.56 Bcfd (76Mtpa) approved for non-FTA export- Total FTA export application submitted to DOE: 41.48 Bcfd (40+ applications)- Total non-FTA export application: 38.06 Bcfd
Company Quantity(Bcfd)
Sabine Pass 2.2
Freeport 1.4
Lake Charles 2.0
Cove Point 0.77 (1.0 FTA)
Jordan Cove 0.8 (1.2 FTA)
Cameron 1.7
Freeport Expansion 0.4 (1.4 FTA)
Oregon 1.25
Carib Energy 0.04 (0.03 FTA)
< non-FTA export approved >
Source: US DOE(as of 2014.10. 21)
New US LNG Export Approval Rule(effective ‘14.5.29)
DOE eliminating conditional approval step for non-FTA
- Review licenses after FERC Environmental Approval
☞ Effect of changing the order in the approval queue ☞ Benefits commercially viable projects, which stand later in
the DOE queue (e.g. Sabine Pass T5-6, Golden Pass)
US LNG Project Regulatory Approval Status
DOE updated the study on the effects of US LNG export for capacity of 12 and 20 Bcfd (87 and 146 Mtpa) (2015-2040)
- Previous study on 6 and 12 Bcfd (44 and 87 Mtpa)
- Domestic NG price of 4%(12 Bcfd) to 11%(20 Bcfd)
KEEI- 15 -
Source: Wood Mackenzie(2014)
US LNG Project Regulatory Approval Status
FERC Queue – by earliest possible authorization date FERC Queue – by earliest possible authorization date
KEEI- 16 -
US LNG Project Peculiarity
Risks Associated with US LNG Imports for TollersRisks Associated with US LNG Imports for TollersCompletion Risk
- Risk of contracted project not built : regulatory, political, local risksSupply Volume Risk - Risk of disruption in supply or failure to arrange supply☞ E&P companies unwilling to sign up a long-term supply – need to develop supply plan Feedgas Costs Risk
- Risk of gas market price(e.g. HH) rising to an uncompetitive level☞ Buyers need ability to ramp down LNG export during cold months with gas price spikes Production Costs Risk
- Risk of gas production cost rising due to environmental, technical challengesPipeline Capacity Risk
- Risk of failing to secure adequate pipeline capacityOther Concerns
- Entry of non-traditional players(independents, MLPs, utilities) into LNG market- Availability of labor and potential for increasing costs and schedule delays
KEEI- 17 -
Conducive to Global Trading activities- US LNG being developed by a
range of developers, supported mostly by traders
- European utilities can leverage PNG and LNG portfolio to capture trading opportunities
- IOCs and Japanese traders can direct LNG to Europe for potential backstop
US LNG Project Peculiarity
< US LNG contracted by off-taker type>
For Asian Buyers, US LNG with flexible terms provides
§ Better position in negotiation & diversified portfolio
§ Eyes towards LNG trading
KEEI- 18 -
West Canadian LNG Projects proposed
Source: Moore et. al.(2014)
3 common sites- Kitimat : Douglas Channel(BC LNG), Kitimat LNG(Chevron), LNG Canada(Shell)- Prince Rupert : Pacific Northwest(Petronas), Prince Rupert LNG(BG)- Grassy Point : Aurora(CNOOC), Woodside
KEEI- 20 -
Merits : rich resources and proximity- Proximity to demand center(E. Asia)- Supply diversity & low political risk- Possibility of relatively rich LNG- Greater value chain participation
West Canadian LNG Projects – Merits and Challenges
Source: Moore et. al.(2014)
Challenges : deliverability- on time and within budget§ Social license to build:
environmental approvals, support from local stakeholders(First Nations) – LNG sites and pipeline routes
§ Cost overruns and labor shortage : potential competition with oil sands projects
KEEI- 21 -
West Canadian LNG Projects – Merits and Challenges
BC gov’t’s LNG income tax (Oct. 21, 2014)- 1.5% → 3.5% → 5% (2037)
Source: Wood Mackenzie
< US GC vs. Pacific NorthWestLNG Prices (Japan, DES) >
KEEI- 22 -
Global LNG Demand in 2025
Asia Pacific LNG demand expected to take up about 70% of global demand in 2025 - (WM) 237 Mt → ~ 460 Mt in 2025
Ø LNG Demand share(2025): Asia Pacific 71%, Europe 20%, ME 3%, SA 1%
Source: IHS Energy
< LNG Demand Outlook by Region (IHS)>
0
50
100
150
200
250
300
350
400
450
500
2000 2005 2010 2015 2020 2025
SouthAmerica
South &East Africa
NorthAmerica
NorthAfrica
Middle East
Europe
Asia Pacific
< LNG Demand Outlook by Region (WM) >
Source: Wood Mackenzie
KEEI- 23 -
Global LNG Supply Potential in 2025
Potential for 650 Mtpa including speculative projects- Atlantic basin 232 Mtpa, ME 99 Mtpa, Pacific 320 Mtpa
Ø North America Potential: 101 Mtpa in 2020, 194 Mtpa in 2025
0
100
200
300
400
500
600
700
2000
2002
2004
2006
2008
2010
2012
2014
2016
2018
2020
2022
2024
West Africa
South America
South & EastAfrica
North America
North Africa
Middle East
Europe
Asia Pacific0
100
200
300
400
500
600
700
2000
2002
2004
2006
2008
2010
2012
2014
2016
2018
2020
2022
2024
Decommissioned
Speculative
Possible
ProbableDevelopment
UnderConstruction
Operational
< Liquefaction Capacity Potential by Region > < Liquefaction Capacity Potential by Status >
Source: Wood Mackenzie
Contents�
I. World LNG Market – Growth and Changing Trends
II. Shale Boom and North American LNG Export Potentials
III. Asian Premium and Cooperation to Improve Asian Gas Market
KEEI- 26 -
Crude oil and natural gas price ratio soars- traditionally 6~10: 1 ratio, but since 2009 the ratio soars
WTI/HH ratio
Sources: Bloomberg, The MLG Group
Oil and Gas Price Ratio Surge
< WTI to Henry Hub Price Ratio >
KEEI- 27 -
Regional Price Divergence
Asian LNG import prices pushed to record high Despite their predominance in the global LNG market, Asian buyers pay a substantial premium for their LNG- oil indexation, tight supply market, lack of alternatives and indigenous production, inelastic demands…
☞ Are regional differentials here to stay? What are the measures to alleviate them?
Source: IEA
KEEI- 28 -
1,000 tons
0246810121416
05,00010,00015,00020,00025,00030,00035,00040,000
1988
1990
1992
1994
1996
1998
2000
2002
2004
2006
2008
2010
2012
Amount of Import
$/MMBTU
400
500
600
700
800
900
1000
Term Contract
$/ton
Korean Recent Term vs. Spot PriceKorean Import Volume and Price
Comparison of Regional Gas Prices
LNG Import Prices
KEEI- 29 -
Stance on Oil Indexation
Asian Buyers Stance
Oil-linked pricing no longer has any rationale- It used to when gas was competing with oil in power sector
Gas supply-demand fundamentals not reflected - Price cannot balance gas demand and supply
☞ Oil Indexation leads to divergence in regional gas prices (Asian Premium)
High capital cost requirement of LNG industry- oil-linked prices required to guarantee a return on large investment
Exploration and development costs are driven by oil pricesLNG prices are tied to alternative fuels such as fuel-oil and diesel
☞ Oil indexation is required to keep it competitive
Suppliers Stance
KEEI- 30 -
Clarifying the Problem Clarifying the Problem l Is the problem the high price level or the price formation?
ü Recent discussions and measures focused on v Changing pricing benchmark index to something other than oil (HH, Hybrid…)v Creating a regional gas hub for a new pricing index in the region
On Asian Gas Premium
- Suppliers contemplating on changing the oil-indexed pricing (Egypt at GECF in 2003, 2004)- Buyers not showing interests
During ‘Buyer’s Market’ situation and when oil price was low
☞ If it is the price formation, what are suitable alternatives?
ü Creating a liquid hub will take time and require other industrial structural changes
☞ If it is the price level, it is a tug-of-war unless the interests are aligned
ü Changing oil-indexation to hub-pricing such as HH can lower the price for nowv What if the oil and gas price ratio changes?v Will the suppliers concede to it? – European renegotiation results suggest…
KEEI- 31 -
energy spot prices2012 dollars per million Btu
Source: EIA, Annual Energy Outlook 2014 Early Release
History Projections
2012
Henry Hub spot price
Brent crude oil spot price
2018 2040
Ratio:7.1
Oil to gas price
ratio:3.4
Ratio:
3.2
EIA projection- US natural gas prices remain well below crude oil prices, but ratio declines
Natural Gas Price Ratio Projection
KEEI- 32 -
0
1
2
3
4
5
6
7
8
9
Mar
14,
201
1M
ay 1
4, 2
011
Jul 1
4, 2
011
Sep
14,
201
1N
ov 1
4, 2
011
Jan
14, 2
012
Mar
14,
201
2M
ay 1
4, 2
012
Jul 1
4, 2
012
Sep
14,
201
2N
ov 1
4, 2
012
Jan
14, 2
013
Mar
14,
201
3M
ay 1
4, 2
013
Jul 1
4, 2
013
Sep
14,
201
3N
ov 1
4, 2
013
Jan
14, 2
014
Mar
14,
201
4M
ay 1
4, 2
014
HH-Indexed vs Oil-Indexed Prices
Source: EIA
Henry Hub Natural Gas Spot Price- Daily price soared to $8.15/mmBtu on Feb. 10, 2014- For monthly average, it reached $6.00/mmBtu in Feb. 2014
KEEI- 33 -
Gas Hub Development and Factors
Gas/LNG Trading
Hub
Gas Supply Infrastructure Connectivity
Many Buyers & Sellers
No Dominant Player(s)
Transparent Price
Formation and
Reporting
Enabling Industry
Regulation & Enforcement
Transparent TPA to
Infrastructure
Source: Holmes(2013, IHS)
Institutional /Structural requirement Japan Korea China Singapore
Hands-off governmentapproach - - - +
Separation of transport & commercial activities - - - +
Wholesale price deregulation + - +/- +
Sufficient network capacityand non-discriminatory
access- - - +
Competitive number of market participants + - + +/-
Involvement of financial institution +/- - - +
< Competitive Market Requirements Comparison >
Source: IEA(2013)
Creating Gas Hub in the RegionCreating Gas Hub in the Regionl Not favorable in all aspects
KEEI- 34 - 34Source: MOTIE, Long-Term Natural Gas Supply and Demand Plans
Domestic Natural Gas Demand Uncertainty
l According to the 11th Long-Term Plan, gas demand for power generation expected to show a free fall, while city gas demand expected to grow üFluctuations and uncertainty of demand in the power sector : gas consumption in the power
sector projected to fluctuate due to cost disadvantage relative to nuclear and coal
KEEI- 35 -
Domestic Natural Gas Demand Forecast Error
l With little cushion in LNG supply, shocks from big errors spread to other customers
(Unit: mill. tons)
ActualLong-term Natural Gas Plans Error Margins
6th 7th 8th 9th 10th 6th 7th 8th 9th 10th
`03 6.47 6.36 1.7%
`04 8.82 7.22 18.1%`05 9.10 6.50 7.61 - - - 28.6% 16.4% - - -`06 10.50 6.73 8.08 - - - 35.9% 23.0% - - -`07 12.08 7.31 8.57 12.22 - - 39.5% 29.1% 1.2% - -`08 11.95 6.23 7.69 12.14 - - 47.9% 35.6% 1.6% - -`09 10.41 4.67 6.65 12.30 12.63 - 55.1% 36.5% 18.2% 21.3% -`10 15.10 4.17 7.35 13.11 14.75 - 72.4% 51.3% 13.2% 2.3% -`11 16.79 4.16 6.99 13.82 15.37 15.35 75.2% 58.4% 17.7% 8.5% 8.6%`12 18.18 4.33 5.87 13.30 15.03 16.30 76.2% 67.7% 26.8% 17.3% 10.3%
`13 20.13 5.62 5.93 13.72 14.49 16.65 72.1% 70.5% 31.8% 28.0% 17.3%
Source: KOGAS (2014)
< Forecast Errors of Gas Demands for Power Generation >
KEEI- 36 -
Need for more flexible Operating Mechanism
High Seasonality & Uncertainty in Demand, and Limited Storage CapacityHigh Seasonality & Uncertainty in Demand, and Limited Storage Capacity
l High demand seasonality requires large storage capacity → reliance on spot cargoes
ü Countries with high swing tend to have higher storage capacity
ü High uncertainty in future demand: demand for gas-fired power generation is highly uncertain
Ø Joint Purchase : a means to bypass the flexibility issue and enhance supply security☞ lessen dependence on spot purchase☞ better utilize storage capacity☞ in itself foster cooperation
- e.g. Kogas & Chubu Electric from Eni (1.7Mt over the period 2013~2017)
KEEI- 37 -
Gas Market Characteristics – Where in the World?
v Limited indigenous gas resources and declining production
v Expectation of increased gas/LNG import dependency
v Gas/LNG imports indexed to oil prices
v Destination and on-sell restrictions for imported gas
v No uniformity in gas industry regulations across individual markets
v Individual markets dominated by national or regional utility monopoliesü High degree or total state-ownershipü Utilities viewed as national championsü Significant employers
v Varying degrees of gas infrastructure connectivity
Excerpts from Holmes, Chris (2013, IHS)
☞ Asia today , …. but could be 1990s Europe
☞ Will things be different for Asian gas market in a decade?
KEEI- 38 -
Factors of Asian Gas PremiumSupply alternatives? - Limited Elastic Demands? - Price insensitiveTrade conducive? - Restrictive and passive
§ Lack of competition, lack of incentive§ Fostering inelasticity in demand§ Over emphasized supply security
Or, Is it ‘Rigidity Penalty’?
The Way Forward
In the mid- to long term, create liquid regional gas market and establish gas hub pricing
In near term, bring in more flexible and hub price-linked volume to alleviate problems of oil linkage
Flexibility issue should be resolved, as it leads to efficient solution through market transactions
Ø Perhaps more problematic than the oil indexed price is the rigidity in trading practice- take-or-pay clause & destination restriction, etc.: … no logical validity☞ hindering efficient development of natural gas market in Asia☞ security of supply threatened with restrictions on trading☞ blocks regional price convergence by preventing arbitrage
Improving Asian Gas Markets
KEEI- 39 -
Measures for Asian Premium and Cooperation for Asian Gas Market
Category Scope Short- to Mid-term Mid- to Long-term
Supply Side Measures
Domestic
• Increase domestic supply• Diversify import sources• Optimize long-term and short-term mix
of imports
• Increase overseas E&P• Build integrated business chain
Regional• Facilitate LNG swaps & joint purchase• Open up upstream sector• E&P technical cooperation
• Cooperate in overseas E&P• Develop joint LNG projects• Build a regional pipeline network
Demand Side Measures
Domestic• Rationalize pricing • Develop alternative power generation
capacity
• Liberalize gas and power and related markets
Regional • Sharing best practices regarding efficiency and pricing policies
• Build a region-wide power grid (other sources of power beyond border)
Trade Side Measures
Domestic• Price deregulation• Easing rigidities in import contracts• Secure more flexible LNG
• Create competitive domestic market
Regional
• Facilitate LNG trade• Share terminals & storage facilities• Efforts to ease contractual rigidities• Enhance data transparency
• Create regional trading platforms• Build a regional pipeline network• Institutional harmonization
KEEI- 40 -
Recent EU Price Renegotiation and Implications
l Changes to more flexibility in pricing and contracting conditions
ü EU companies’ price renegotiation results v With liquid market customers – introduce spot market price indexation v With illiquid market customers – reduce oil indexation level, without spot price
indexation
ü EU competition policy : succeeded elimination of destination clause and more pressurev Recent launching of investigation against Gazprom for hindering competition in
Central/Eastern European gas markets
< Russia LT Oil indexed Price and NBP >
KEEI- 41 -
LNG Market Trends Recap and Bottom Line
Global LNG market is evolving to more short-term oriented and flexible - while long-term contracts still mainstream, non long-term trades rapidly growing - number of importers and exporters continue to increase, naturally leading to more short-term and spot deals, and arbitrage deals
North American LNG can bring considerable impact through flexible contractual terms- no destination restriction, less stringent volume offtake requirement with US LNG- helps increase overall flexibility in LNG supply, breaking away from oil-linked pricing- more flexible LNG supply needs more shipping, more regasification units, and more
parties involved in the market- are we ready for the changing dynamics coming from North America and make best of
the changes to improve Asian gas market?
Korea and other Asian buyers need flexibility in LNG trade for their high seasonality of demand and substantial consumption volumes
- with 3/4 of global LNG trade, Asian buyers should be able to pilot a change to establish trading practice to tailor their needs
- being passive with inelastic demands will get us nowhere in 10 years and on