New Business Models (Gas Pricing &
Financing) in the New Era of GasPresented at
The 7th International Indonesia Gas
Conference and Exhibition
1
The 7 International Indonesia Gas
Conference and Exhibition Presented by
Dr. Fereidun Fesharaki
Chairman, FGE
January 27, 2015
This presentation material contains confidential and privileged information.
The dissemination, distribution, or copying by any means whatsoever without FGE’s prior written consent is strictly prohibited.
Who is FGE?� For over 30 years, FGE has delivered strategic advice on the oil and gas markets to clients around the
world. The company was the first consulting firm to specialize in the downstream oil and gas markets with
a focus on the East of Suez region.
� Over the past decades, FGE has provided studies and advisory services to national governments, national
oil and gas companies, major oil and gas companies, independent oil and gas companies, financial
institutions, international and intergovernmental organizations, utilities, consultancies, and engineering
design firms.
� FGE’s global presence enables us to service clients around the world.
Over 270 Clients Around the Globe
2
Please visit our website,
www. FGEnergy.com for more information.
Beijing
SingaporeHonolulu
Dubai
London
Main Offices
Rep/Branch Offices
Global/Asian Headquarters
TokyoCalifornia
Melbourne
Mumbai
� Need for consistent integrated oil and gas policy in the era of volatile oil
prices.
� Since many new gas projects are high cost offshore gas, huge challenges
are faced by the industry to proceed forward. Incentives need to be
provided.
� Imported LNG is inevitable. Pricing of LNG imports will be much lower
New Paradigm for Indonesia
3
than expected in the past. A consistent relationship between domestic
and international prices needs to be established.
� Project financing will become more challenging in the era of lower oil
prices. There is a role for the State in facilitating and incentivizing
innovative project financing.
� There is a need to develop institutions along with policies to ensure
proper implementation, free of political wrangling.
�OPEC size addition to oil production New
� Largest producer of condensates in the world (now) New
�Amongst top 3 LNG exporters in the world (by 2020/22) New
�Top LPG exporter in the world (by 2015/16) New
The US as an Energy Superpower
4
Top LPG exporter in the world (by 2015/16) New
� Largest exporter of refined products in the world (now) New
�Emerging major petrochemical exporter (by 2020) New
�Emerging ethane exporter New
�Major coal exporter
$70
$80
$90
$100
$110
$120
$130
US$/bbl Brent (2005-2020)
Long-Term Oil Price: Finding A New Balance
5
$-
$10
$20
$30
$40
$50
$60
52005–2014: actual, forecast in $2014 thereafter
$40
$60
$80
$100
$120
US$/bbl Brent (Jan 2014-Dec 2015)
Massive Supplies Planned Post-2017…
…But Buyers Need to Commit!
500
600
700
800
900
mm
t
World Liquefaction Capacity and LNG Demand
Speculative
Planned
Under Construction
In Operation
6
0
100
200
300
400
500
mm
t
World LNG Demand
250
300
350
mm
t
Likely East Africa Exports to Asia*
Likely Canada Exports to Asia
Likely US Exports to Asia
Likely East of Suez Supply Capacity
Targeting Asia Pacific
Asia+ME Demand
2014: Supply required
from West of Suez
East of Suez LNG Market Pressure PointsEast of Suez Liquefaction Supply and LNG Demand
Market softens. No huge
surplus, uncompetitive projects
fail to materialize.
7
100
150
200
2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
from West of Suez
Base case scenarios (JKTIC + New Markets + Middle East)
*Only Mozambique for now
Australian ramp up.
US supplies start.
Canadian and East African projects add to supplies.
Myth: No More Oil-Linked Deals Being Done
HH-
Linked, 3
0%
Oil-
Linked, 6
0%
Number of Contracts:*
Share by Type (2013-Present) HH-
Linked,
5.6
mmtpa
Hybrid,
Oil-
Linked, 1
9.2
mmtpa
Contracted* Volumes
(2013-Present)
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*Mid- to long-term contracts signed since early 2013 by Asian end-user buyers only,
excluding contracts concluded for resale purposes.
More contracts signed and the most volumes contracted
were either oil or hybrid-linked!
Hybrid, 1
0%
Hybrid,
7.7
mmtpa
Long-Term Oil vs. Hub Indexation—Which is Better? Projected Oil- and Hub-Linked LNG Prices Delivered to Asia
9
In comparing the oil-indexed contracts and hub-indexed LNG prices delivered to Asia, a range of HH prices
is considered. A lower case (EIA’s 2014 Outlook) and higher case (FGE Outlook) for HH prices are used as
the basis of hub-linked LNG contract prices.
HH-linked contracts are not necessarily cheaper but may offer greater flexibility in non-pricing terms.
Spot/Short-Term Buying has Risen Substantially
15%
20%
25%
25
30
35
40
45
mm
tMiddle East
Thailand, Singapore & Malaysia
China
India
Taiwan
South Korea
Japan
Spot/Short-Term Share of East of Suez Trade (RHS)
10
0%
5%
10%
0
5
10
15
20
25
2006 2007 2008 2009 2010 2011 2012 2013
mm
t
Asia is the Biggest Driver in Global Trade
0
10
20
30
40
2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013
% c
ha
nge
ye
ar
on
ye
ar
Global LNG Imports, 2001-2013
Y-O-Y Change
11
Europe
14%
Asia
75%
Americas
9%
Middle
East
2%Europe
23%
Asia
72%
Americas
5%
-20
-10
2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013
Middle East Americas Asia Europe
2013:
236 mmt
2000:
101 mmt
Besides Japan, Korea, and Taiwan, which will be under pressure to secure additional
supplies, new demand is emerging from Southeast Asian importers
Who Holds the Biggest Potential in Signing New
Contracts?
60
80
100
120
mm
tpa
Uncontracted LNG Demand*
12
*Likely uncontracted demand including contract renewals and likely preliminary agreements.
Contractual supplies exclude optional volumes and additional volumes.
-
20
40
2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
mm
tpa
New Markets Uncontracted Demand India Uncontracted DemandChina Uncontracted Demand Taiwan Uncontracted DemandKorea Uncontracted Demand Japan Uncontracted Demand
• US • Under construction – 34.95 mmtpa
• Announced* – >260 mmtpa
• Canada• Announced* – >310 mmtpa
“New Frontiers” of Supply – Big Bonanza?
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• Russia• Under construction – 16.5 mmtpa
• Announced – 63.9 mmtpa
• East Africa• Announced – up to 32.5 mmtpa**
*Capacity per DOE authorization to FTA countries for US, NEB authorization for Canada.
**Mozambique project partners’ original plan includes up to 50 mmtpa but 20 mmtpa landed + 2.5 mmtpa FLNG in 1st phase. Tanzania is 10 mmtpa.
FIDs delayed?
Sellers Roll the Dice—Build Supply or Not?
� EPC and upstream costs high all over
Upstream increasingly difficult conditions
Australian budget blowouts…may shift to US
� Buyers’ LNG price expectations too low
Landed at US$12/mmBtu not doable for many projects
� Fiscal terms and sovereign risk unfavorable
Egyptian FMs, YPF nationalization, Israel…
Planned projects may not
eventuate…
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� Oil and gas producers overextended
Increasing consolidation and asset sales
� Contract flexibilities and price basis (hub, hybrid) hamper project finance
Some US finance costs expensive
� Use existing infrastructure to monetize gas assets, delaying production
Arrow LNG? Bonaparte LNG?
� Postpone? Cancel?
Kitimat LNG?
Thank You
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