xto merger
TRANSCRIPT
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ExxonMobil / XTO Merger
R.W. Tillerson and D.S. RosenthalJuly 8, 2010
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Cautionary Statement
Forward-Looking Statements. Outlooks, projections, estimates, targets, business plans, and other statements of
future events or conditions in this presentation or the subsequent discussion period are forward-looking
statements. Actual future results, including supply and demand growth and mix; ExxonMobils production
growth and mix; the amount and mix of capital expenditures; resource additions and recoveries; finding and
development costs; project plans, timing, costs, and capacities; cost efficiencies; product mix; the impact of
technology; and benefits and effects of the XTO Energy transaction could differ materially due to a number of
factors. These include changes in long-term oil or gas prices or other market conditions affecting the oil, gas,
and petrochemical industries; reservoir performance; timely completion of development projects; war and other
political or security disturbances; changes in law or government regulation; the outcome of commercial
negotiations; the actions of competitors; unexpected technological developments; the occurrence and duration
of economic recessions; unforeseen technical difficulties; our ability to integrate effectively XTO Energy's
business; and other factors discussed here and under the heading "Factors Affecting Future Results" in the
Investors section of our Web site at exxonmobil.com. See also Item 1A of ExxonMobils 2009 Form 10-K.Forward-looking statements are based on managements knowledge and reasonable expectations on the date
hereof, and we assume no duty to update these statements as of any future date.
Frequently Used Terms. References to resources, resource base, recoverable resources, and similar terms
include quantities of oil and gas that are not yet classified as proved reserves but that we believe will likely be
moved into the proved reserves category and produced in the future. XTO Energys proved reserves" discussed
in this presentation are presented on the SEC basis. For definitions of, and information regarding, certain termsused in this presentation, including information required by SEC Regulation G, see the "Frequently Used Terms"
posted on the Investors section of our Web site. The Financial and Operating Review on our Web site also
shows ExxonMobil's net interest in specific projects.
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$36 billion transaction, includes assumption of $11 billion of debt
45+ TCFE resource base, under $1/KCFE resource capture
~485 KOEBD production: 2.4 BCFD of natural gas and 85 KBD of liquids
Foundation for Global Unconventional Resource Company in-place
ExxonMobil / XTO Merger is Complete
XTO provides material, high-quality additions to our resource base andestablishes the premier global unconventional resource company.
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Accounting
Acquisition accounting Step-up of assets and liabilities to fair market value
Hedging XTO hedged 2010/2011 production; fair market value recognized at closing ExxonMobil will receive cash flow consistent with hedging terms
Hedges will provide minimal earnings impact
Transaction increases production and operating cash flow
Additional shares result in dilutive impact on earnings per share Outstanding shares increased by ~9%
Finance
Anticipate share purchases to reduce shares outstanding of $3B in 3Q 2010
Consider opportunistic debt restructuring where economic
Capex plans essentially unchanged
Financial Impacts
Accretive to production and cash flow; dilutive to EPS near-term.
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ExxonMobil is the largest producer of natural gas in the U.S.
U.S. Natural Gas Production 1Q 2010
0
500
1000
1500
2000
2500
3000
3500
4000
XOM / XTO APC CHK BP DVN ECA COP CVX RDS
Average U.S. Daily ProductionMCFD
Source: Natural Gas Supply Association
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0
50
100
150
200
250
300
350
1980 2005 2030
World Gas Demand
Energy Demand
MOEBD
Gas by Sector
BCFD
Oil
Gas
Coal
Other
0.8%
1.8%
0.5%
1.8%
0
100
200
300
400
500
1980 2005 2030
Residential
Commercial
Industrial
Power
Generation
Transportation
1.1%
1.4%
2.5%
5.4%
Average Growth / Yr.
2005 - 2030
1.2%
Natural gas demand is growing at 1.8% annually, driven primarily bygrowth in demand for power generation.
Source: The Outlook for Energy, 2009
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0
25
50
75
2000 2015 2030
U.S. Gas Supply and Demand Balance
All Sources
BCFD
Conventional
Unconventional
Pipeline & LNG
Unconventional gas is expected to almost double between 2010 and 2020more than offsetting decline in conventional natural gas supplies.
U.S. demand is increasing
Conventional gas supply will fallover 50 percent by 2030
Unconventional gas will more thanoffset decline Supply is expected to reach over
40 BCFD by 2030
Pipeline supplies and LNG importswill meet balance of demand
Source: The Outlook for Energy, 2009
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45 TCFE with significant upside and material positions in allunconventional resource types.
Resource Base Five major shale gas plays
account for over half of resource base
Freestone Trend provides tight and
conventional gas production
Coal bed methane and tight gas playsin the Rockies
Liquids concentrated in Permian Basin
and Bakken Shale
Additional upside New plays (e.g. Bossier Shale) Increased recovery
XTO Resource Base
Freestone
Trend
Shale
Gas
Liquids
Other
Gas
45 TCFE
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Material positions in 5 major U.S. shale gas plays, with strong oil position inthe Bakken Shale.
XTO Resource Base Shales
Bakken Shale450,000 net acres
Barnett Shale265,000 net acres
Woodford Shale160,000 net acres
Fayetteville Shale380,000 net acres
Marcellus Shale280,000 net acres
Haynesville Shale165,000 net acres
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45+ TCFE resource base provides future drill well inventory in excessof 10,000 wells.
Current resource to production ratiois over 40 years Long-life production
Anticipate continued ramp-up indrilling activity Currently operating ~70 rigs Up ~50% versus year-end 2009
Accompanied by steady rise inproved reserves
Large, Low-Risk Drilling Inventory
Finding and Development Costs$ per KCFE
0.00
0.40
0.80
1.20
1.60
2.00
BarnettCore
Fayetteville Woodford HaynesvilleMarcellus
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Proven ability to consistently and profitably grow production.
Leading U.S. gas producer 2.4 BCFD production in 1Q 2010
Over 85 KBD liquids production Growth potential in Bakken Shale
and Permian Basin
Significant resource base underpinsfuture production growth potential
XTO Production
0
500
1000
1500
2000
2500
3000
3500
2006 2007 2008 2009
XTO Average Daily ProductionMCFE/D
OilNatural Gas LiquidsNatural Gas
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Demonstrated high-quality operator across multiple play types, with cashoperating costs under $2/KCFE.
Strong operating culture
Focus on safety, operationsintegrity, and the environment
Unit costs stable despite volatileindustry service costs
1Q 2010 cash operating costs$1.69/KCFE
Solid cash flow from operations
Low Cash Operating Cost
0.00
0.50
1.00
1.50
2.00
2.50
3.00
2006 2007 2008 2009
XTO Cash Operating Cost*$ per KCFE
Taxes, transportation, other expenseProduction expense
* Source: XTO historical reported values. Cash operating cost includes production,tax, and transportation expenses. Excludes exploration, gas gathering and
processing, and general and administrative expenses.
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ExxonMobil / XTO Portfolio
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Strong position with opportunities in all resource types and spanning thefull range of play maturities.
ExxonMobil / XTO U.S. Unconventional Plays
Shale Gas
Tight Gas
Coal Bed Methane
Shale Oil
Bakken
Marcellus
Fayetteville
Haynesville/Bossier
Woodford
Barnett
Freestone
San Juan
UintaPiceance
Eagle Ford
Raton
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GermanyPoland
Canada
United States
Argentina
Indonesia
Global Unconventional Resource Portfolio
ExxonMobil has assembled a substantial, global unconventional gasportfolio and we continue to capture high-quality additions.
Shale Gas
Tight Gas
Coal Bed Methane
Shale Oil Over 8 million total acres
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The combination of ExxonMobil and XTO enhances resource andshareholder value.
Proven capabilities to developall resource types
Opportunity to further enhancefinancial and operating performance
Financial strength and provenproject management skills
Accelerate evaluation and
development of highest-quality plays Long-term commitment to research
will deliver advantaged technologies
A Value-Added Combination
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Summary
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Unconventional Gas and Oil
Arctic
ExxonMobil has the industrys largest, highest-quality resource base and iswell-positioned for profitable future growth.
ExxonMobil Resource Base Post-Merger
0
30
60
90
YE 2009
Conventional
Heavy Oil / Oil Sands
Deepwater
Acid / Sour Gas
Liquefied Natural Gas
BOEBResource Base*
High-quality resources in allgeographic regions ~50% in the Americas
Diverse by resource type
Continue to grow our resourcebase through: By-the-bit drilling success Undeveloped resource capture Improved recovery from existing
fields
* Combined resource base for ExxonMobil and XTO using YE 2009 data.The Unconventional Gas and Oil category also includes Bakken shale oil resources.
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Proven Business Model No Change
Delivers superior results and provides a unique, competitive advantage.
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Summary
Industry-leading portfolio of businesses and assets
Disciplined approach to operational excellence and risk management
Superior financial flexibility
Commitment to technology leadership
Long-term perspective
Disciplined focus on maximizing long-term shareholder value whilemaintaining our commitment to safe operations and the environment.
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Addendum
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United States Net Acreage (K)Barnett Shale 265
Woodford Shale 210
Fayetteville Shale 380
Marcellus Shale 425
Haynesville / Bossier Shale 215Eagle Ford Shale 50
Bakken Shale 450
Freestone Trend 380
San Juan-Raton Basins 400
Uinta Basin 265
Piceance Basin 300
Total U.S. 3340 Total International 4770
Unconventional Acreage
ExxonMobil has over 8 million acres of unconventional resourcesspanning all resource types.
Canada Net Acreage (K)Horn River Basin 310
Germany
Lower Saxony Basin 850
Coal Bed Methane 1850
Poland
Podlasie and Lubline Basins 1360
Indonesia
Barito Basin CBM 290
Argentina
Neuquen Basin 110
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