New Pricing Realities in Oil & Gas Aspen Institute Forum on Global Energy, Economy, and Security
Jason Bordoff Columbia University
June 10, 2015
Aspen, Colorado
420 West 118th St, New York, NY 10027 | http://energypolicy.columbia.edu | @ColumbiaUEnergy
2
The 2014-2015 Oil Price Drop Magnitude and Impact
Source: EIA, Bloomberg
-100% -80% -60% -40% -20% 0%
1997-1998
2014-2015
1985-1986
2008-2009
Major Oil Price Collapses in Recent Oil Market History Peak to trough % decline
• The magnitude of the 2014-2015 oil
price drop is comparable to the biggest
oil price collapses in recent history
• The shape of the oil price recovery has
been of much debate, but general
consensus holds that—short of a major
supply shock—oil prices will likely stay
below $100 for an extended period
• Many questions remain about the ‘new
world of oil’:
• What is going to balance the
market? ‘Call on US shale’?
• Greater or lesser volatility with new
Saudi policy?
• Will Saudis maintain policy?
• What about non-OPEC, non-shale?
3
The 2014-2015 Oil Price Drop Winners and Losers
Source: IMF, Citi, Reuters
Oil consumers worldwide
• $50 price drop is equivalent
to $1.5 tn reduction in
spending on oil annually
The global economy
• Global GDP growth boosted
by up to 0.7 percentage
points in 2015 and by up to
0.9 percentage points in
2016 (IMF)
Subsidy reform
Subsidy reforms in India,
Indonesia, Malaysia, Kuwait,
Egypt, collectively representing
nearly 25% of global fossil fuel
subsidies in 2013
Winners Losers
Major producers
• Oil export revenue (OPEC minus Iran) down $100B
in 2014 and set to drop $350B in 2015
• Nigeria: post-election violence largely averted, GDP
outlook pulled down by 2.5% to 4.8% in 2015 by oil
price drop
• Venezuela: GDP projected to drop 7% and inflation
reach 96% in 2015
• Russia: GDP is set to drop by 3.8% in 2015 (IMF) as
a combined result of sanctions and the oil price drop
• Saudi: drew ca. $58 billion from reserves between
Aug ’14 and Apr ‘15
The oilfield services and majors
Upstream CAPEX cut by 20% in ‘15 vs. ‘14
Impact on gas and renewables?
Coming soon from CGEP…
4
Implications for Global Demand
• Strong demand response in Q1
2015 surprised to the upside
• OECD Europe: total oil
demand up by 3.9% y/y in
1Q15
• US: gasoline demand up
3.3% y/y in 1Q15
• India: diesel demand up by
9.3% y/y and gasoline
demand up by 18.7% y/y in
April
• Demand response may be limited
by global macro headwinds (e.g.,
China), strong dollar,
macroeconomic impacts in net oil
exporters, and other factors
-8% -6% -4% -2% 0% 2% 4% 6% 8%
Korea
Europe 5*
India
China
Australia
US
Japan
Q1 '15 vs. Q1 '14
2015 vs. 2014 (est.)
-8% -6% -4% -2% 0% 2% 4% 6% 8%
Saudi Arabia
Iran
Brazil
Russia
Canada
Mexico
Venezuela
Q1 '15 vs. Q1 '14
2015 vs. 2014 (est.)
Source: IEA, JODI
Oil Product Demand in Selected Major Oil Importing Countries
% change y-o-y
Oil Product Demand in Selected Major Oil Exporting Countries
% change y-o-y
5
Implications for Global Supply Time to Redraw the Cost Curve
Source: Citi, Morgan Stanley, Rystad Energy
• High cost projects (e.g. deepwater, oil sands, Arctic) will be challenged at lower oil prices
• High capex megaprojects will probably be needed in the future, but more than $100 billion of
new spending has already been delayed or cancelled
• Is the current price slump setting the stage for another underinvestment cycle as in the 1990s?
• Not only prices, but also costs have come down significantly in 2015 vs. 2014 (ca. 10-20% for
high capex projects and up to 20-40% in US shale plays)
Global Liquid Supply Cost Curve
$ per barrel breakeven
Upstream Capex Set to Decline 20% y-o-
y
$ billion
6
High Cost Projects Pain and Relief
Deteriorating economics
• A substantial portion of pre-sanction
projects do not break even at today’s
oil price levels
CAPEX reductions
• US and Canada account for the vast
majority of capex cuts
• Other high cost areas are more likely
to see deferrals, projects with sunk
costs will likely continue
Higher cost of capital
• Cost of capital and hurdle rates may
rise in more volatile environment
• Fed monetary policy is key to
production outlook
Cost compression
• Service costs have come down substantially
across the board
Efficiency improvements
• Productivity improvements ~25% pa
• Standardization and cost discipline is gaining
ground in deepwater
Fiscal relief
• Countries with high cost production appear
willing to offer better fiscal terms to retain
investments (e.g. UK tax cuts, Brazil
considering local content waivers)
Currency movements
• Non-US producers benefit as much of the costs
are in local currency while revenues are in USD
Challenges Offsets
7
Is the US the World’s New ‘Swing Supplier’?
Source: EIA, Baker Hughes
• US rig count down by 55% since Oct
’14, but production up to 9.6mbd in
May ‘15
• Saudis as high as 10.5 mbpd in May
• US tight oil production resilient, and
don’t forget rising offshore production
• Has market balancer role shifted to
US?
• Swing producer or marginal
producer?
Key uncertainties:
• Shape of the supply curve
• Access to capital
• Productivity gains and high-grading
• Service cost compression
• Partially drilled but uncompleted wells
0
25
50
75
100
125
150
0
400
800
1,200
1,600
2,000
2,400
Jan-
10
Jun-
10
Nov
-10
Apr
-11
Sep
-11
Feb
-12
Jul-1
2
Dec
-12
May
-13
Oct
-13
Mar
-14
Aug
-14
Jan-
15
US vs. Saudi Rig Count No. of rotary rigs operating
US Rig Count - LHS
Saudi Rig Count - RHS
5
6
7
8
9
10
0
500
1000
1500
2000
2500
Jan-
13
Apr
-13
Jul-1
3
Oct
-13
Jan-
14
Apr
-14
Jul-1
4
Oct
-14
Jan-
15
Apr
-15
Jul-1
5
Oct
-15
Jan-
16
Apr
-16
Jul-1
6
Oct
-16
US Crude Oil Production and Rig Count
US Crude Production - RHS
US Rig Count - LHS
8
‘Call on US Shale’ Not Quite Swinging Yet
Source: Citi, EIA, EBW Analytics
• So far, mainly stock builds and demand response have balanced the oversupplied oil market
• Increased or decreased price volatility?
• US shale can respond faster than conventional, but not as fast as Saudis
• High Saudi production leaves little spare capacity buffer, although OPEC’s role as
effective cartel has long been overstated
• Light sweet buffer more effective than heavy sour one in dampening Brent & WTI
spikes
• Atlantic Basin overhang plus weight of global inventories provides some cushion too
EIA Revision of US Crude Production (Jun vs. May ’15)
Million b/d
9
Crude Export Policy Affects Production & Trade Outlook
Source: EIA, Bloomberg
• US crude exports are already up sharply thanks to Canada, Commerce FAQs, product exports,
and potential swaps with Mexico in the near future. West African light oil displaced.
• Consensus emerging about beneficial impacts lifting the crude oil export ban, but remains
politically challenging. Movement building on Capitol Hill.
• Slowdown in US supply growth & narrow LLS-WTI-Brent spreads raise questions about
urgency of issue. Low gasoline price raise concerns about rebound being attributed to policy
change.
-4,000-3,000-2,000-1,000
01,0002,0003,0004,0005,0006,000
Jan-
00
Feb
-01
Mar
-02
Apr
-03
May
-04
Jun-
05
Jul-0
6
Aug
-07
Sep
-08
Oct
-09
Nov
-10
Dec
-11
Jan-
13
Feb
-14
Mar
-15
US Exports and Imports of Petroleum Products and Crude Oil Exports Thousand barrels per day
Gross Exports - ProductsGross Exports - CrudeGross Imports - ProductsNet Imports - Products
0
20
40
60
80
100
120
140
160
Jan-
10
Jul-1
0
Jan-
11
Jul-1
1
Jan-
12
Jul-1
2
Jan-
13
Jul-1
3
Jan-
14
Jul-1
4
Jan-
15
Brent WTI and LLS Prices $ per barrel
Brent
LLS
WTI
10
What About the Rodney Dangerfield Barrels?
Source: Goldman Sachs
• Goldman Sachs believes US shale + Iraq + already committed and low breakeven projects
are sufficient to meet global demand through 2020
• What about high capex long-lead time projects (e.g. deepwater, oil sands)?
Breakeven Cost of Oil Production by Category
$ per barrel
11
Deepwater Cost Curve Shifting Lower, But Delays Are Likely
Source: Goldman Sachs
• The industry has poor track record of delivering
deepwater megaprojects at cost and on budget, even
at high oil prices
• Price pressure focuses minds on efficiency e.g. via
standardization and better planning
• Cost compression (partly due to pre-2014 overbuild
cycle) also provides some relief
• Brazil: most pre-salt projects break even below $60,
but Petrobras’ troubles may limit investment outlook
• West Africa: most pre-sanction deepwater projects
in Angola and Nigeria are high breakeven ($60+),
high risk of delays and cancellations without fiscal
relief
• US GoM: development of large discoveries in Lower
Tertiary remain economic thanks to better than
expected flow rates (15+ kbpd) and cost deflation
Deepwater Is Among the Worst-Hit Project Type
Split of major pre-sanction development projects with $60+ breakeven by development type
12
North Sea Lower Oil Prices are Just Another Challenge
• North Sea oil has long been challenged by
high development and production costs,
ageing infrastructure and looming
decommissioning liabilities
• Short-term production impact not yet apparent
• Medium-term outlook shifted from marginally
positive to marginally negative (ca. 100 kbpd
decline forecasted by Citi in each of the next
two years)
• Smaller projects and field redevelopments
offset some of the mature field declines
• High-capex projects will likely be delayed, but
tax breaks (e.g. in UK) and service cost
deflation can partially offset the negative
impact of the oil price drop
13
Canadian Oil Sands Long-Term Outlook Sharply Downgraded
• Most Canadian oil sands developments (esp.
mining) are not economic at today’s oil prices
• Long-term (2030) production outlook cut by 1.1
mbpd (from 6.4 mbpd to 5.3 mbpd)
• Canadian production will increase through 2020,
albeit at a slower pace than expected (+140 kbpd
vs.+ 210 kbpd annually, according to the IEA)
• As of mid-May, nine major Canadian oil sands
projects had been deferred due to the price drop
• Capex cuts and delays will primarily affect
production post-2016, already sanctioned
projects will not likely to be stopped by lower
prices
• Alberta’s new social democratic government
presents further uncertainties to the investment outlook
Canadian Project Delays and Cancellations
Source: Rystad Energy, Morgan Stanley
Canadian Oil Sands Projects on the Cost Curve
14
Russia Short-Term Resilience, Medium-Term Struggle?
Source: Citi, Bank of America
• Russian production has proved resilient in
the short-term (up by 100 kbpd y/y in Q1 ’15)
• Ruble cost deflation and efficiency gains
have helped offset impact of lower oil prices
in the short-term
• Medium-term outlook is more negative as
lower oil prices and Western sanctions weigh
on investments
• IEA expects Russian production to drop by
560 kbpd in ‘14-’20, Bank of America
forecasts 300 kbpd drop in ‘15-’19
• Greenfield developments in East Siberia,
tight oil development in the Bazhenov basin
(previously expected to produce at 500 kbpd
by 2018) and field redevelopment projects in
mature areas will be hardest hit
Russian Oil Production Up in the Short-Term Million b/d
Russian Oil Production Growth in the Medium-Term Million b/d
15
Arctic A Long-Term Bet On Healthy Oil Prices and Demand
• Arctic developments are not viable at
today’s oil prices…
• … but Arctic exploration is a long-term play
with at least 10 to 15-year development
cycle – current price outlook is irrelevant, if
operators expect high prices and
continuing oil demand growth in the 2030+
time horizon
• Shell continues drilling campaign in Alaska,
Chevron pulled out of Beaufort Sea drilling
program in Canada, Exxon’s Kara Sea
exploration suspended due to sanctions
against Russia, some Norwegian projects
have been pushed to the right
• Environmental opposition may prove as big
of a challenge as engineering and
economics
16
Implications for Global Crude Oil Flows
• North American production growth will continue, backing out further seaborne imports, albeit at
slower pace than previously expected – net imports decrease less than expected through 2020
• The Atlantic Basin has shifted into a persistent crude surplus due to the displacement of light
sweet African crudes from North America, keeping Brent in a structural contango
• Europe and Asia are increasingly import-dependent, but Asian buyers enjoy more leverage as
exporters compete aggressively for market share (see Saudi OSPs)
• Canadian and Mexican crudes will be increasingly exported outside North America through
2020; about 300 kbpd of US condensate can also be exported outside the region
• US crude oil export restriction and Iran negotiation are key uncertainties for trade flows
17
Implications for Global Refined Product Flows
• Product markets will continue to expand and globalize in the medium-term thanks to growing
product exports from the US, Asia and the Middle East
• US has emerged as the world’s largest gross oil product exporter and it is projected to become
a net exporter of gasoline by 2017 (IEA). Crude export restrictions drives more product exports.
• With the ‘hollowing out’ of the European refining sector, Europe will become increasingly
dependent on middle distillate imports
• The Middle East is not only exporting record amount of crude but also refined products from a
number of new mega-refineries
18
Implications for Global LNG Flows US Export Story Not Over
Source: Wood Mackenzie, Citi Research
Map of Future Global Gas Flows • Sabine Pass starts 2015; Cameron,
Freeport, Cove Point under
construction (51mtpa vs Qatar 77
mtpa); >2 FIDs planned for 2015
• Some US projects may be pushed
out; less advanced probably
cancelled (costly FERC approval)
• US LNG is well-positioned in the
global competition (mainly
brownfields with ready access to
developed natural gas sources)
• Closing of the arbitrage gap between
US and Asia/Europe is likely
temporary, and only affects
uncontracted projects
• US exports look increasingly
competitive in Europe
Thank you
For more information contact
Jason Bordoff Professor of Professional Practice in International and Public Affairs
Founding Director, Center on Global Energy Policy
Columbia University
(212) 851-0193