exv99


Introduction			1
Business Model			2
Corporate Overview			4
The Outlook for Energy			6
Safety, Security, Health & Environment			10
People and Technology			12
Financial Highlights			14
Upstream			24
Downstream			72
Chemical			88
Frequently Used Terms			98
Index			102
General Information			103

The term Upstream refers to exploration, development, production, and gas and power marketing. Downstream refers to the refining and marketing of petroleum products such as motor fuels and lubricants.

Statements of future events or conditions in this report, including projections, targets, expectations, estimates, and business plans, are forward-looking statements. Actual future results, including demand growth and energy mix; capacity growth; the impact of new technologies; capital expenditures; project plans, dates, costs, and capacities; production rates and resource recoveries; efficiency gains; cost savings; and product sales could differ materially due to, for example, changes in oil and gas prices or other market conditions affecting the oil and gas industry; reservoir performance; timely completion of development projects; war and other political or security disturbances; changes in law or government regulation; the actions of competitors and customers; unexpected technological developments; the occurrence and duration of economic recessions; the outcome of commercial negotiations; unforeseen technical difficulties; unanticipated operational disruptions; and other factors discussed in this report and in Item 1A of ExxonMobil’s most recent Form 10-K.

Definitions of certain financial and operating measures and other terms used in this report are contained in the section titled “Frequently Used Terms” on pages 98 through 101. In the case of financial measures, the definitions also include information required by SEC Regulation G.

“Factors Affecting Future Results” and “Frequently Used Terms” are also posted on the “investors” section of our Web site.

Prior years’ data have been reclassified in certain cases to conform to the 2010 presentation basis.

ExxonMobil safety and environmental information does not include XTO Energy Inc. data. All other data includes XTO data from the time of the acquisition (June 25, 2010) onward, unless otherwise noted.

Integrity

Integrity – in every sense of the word – defines how we take on the world’s energy challenges. It is the reason for our success.

ExxonMobil believes that our commitment to integrity – our systematic and unwavering focus on safety, operational excellence, financial discipline, and high ethical standards – is the driving force behind our industry-leading returns. It enables us to manage risks effectively, maximize our long-term returns, and be best-positioned to meet the world’s growing energy needs.

Meeting energy demand safely, while minimizing the impact on the environment, is a mission unlike any other. Energy – for electricity, for transportation, for industry – is fundamental to economic and social progress and to the lives of billions of people. We must meet the energy needs of the current generation while protecting the environment for future generations.

ExxonMobil understands the scope of the challenge. We know that despite recent economic weakness, global energy demand in 2030 is expected to be 35 percent higher than it was in 2005. We know the world will need more cleaner-burning fuels, particularly natural gas. We know it will require unprecedented levels of capital investment.

To meet demand through 2030 and beyond, ExxonMobil continues to expand and diversify our resource base, promote efficiency, and develop new energy technologies. Our focus on integrity enables ExxonMobil to not only safely produce solutions for the world’s evolving energy needs, but also to produce long-term value for our shareholders.

Rex W. Tillerson, Chairman and CEO

ExxonMobil’s business model and fundamental strategies are key to achieving sustained, outstanding performance in all aspects of our business. Through the superior execution of these strategies and a foundation based on integrity, ExxonMobil is able to meet the challenge of providing reliable, affordable energy in a responsible manner while delivering long-term value for our shareholders. Corporate

Business Model and Fundamental Strategies

ExxonMobil has a consistent and straightforward business model that combines long-term perspective, focus on operational excellence, delivery of superior cash flow, and disciplined approach to capital investment to grow shareholder value. Our business model is enduring. Testing our projects across a range of economic scenarios ensures resiliency throughout the business cycle and enables us to continue to deliver superior long-term value to our shareholders.

OPERATIONAL EXCELLENCE

Operate in a Safe and Environmentally Responsible Manner Our commitment to safety, security, health, and the environment creates a solid foundation for superior results in all aspects of our business. ExxonMobil’s senior management and employees are committed to operational excellence, and this objective is deeply embedded in our culture. Our long-term safety performance continues to lead industry, and we improve environmental performance by driving environmental incidents with real impact to zero. We conduct business using an approach that is compatible with both the environmental and the economic needs of the communities in which we operate.

Uphold High Standards ExxonMobil believes that a well-founded reputation for high ethical standards, strong business controls, and good corporate governance is a priceless corporate asset. This means that how we achieve results is as important as the results themselves. We choose the course of highest integrity in all of our business interactions. Directors, officers, and employees must comply with our Standards of Business Conduct. ExxonMobil adheres to all applicable laws and regulations as a minimum standard, and, when requirements do not exist, we apply responsible standards to our operations. We have developed a wide range of management and operating systems that address critical aspects of our business. The disciplined application of these management and operating systems, deployed through our functional organization, has consistently delivered superior results.

Attract and Retain Exceptional People Delivering outstanding performance requires exceptional people. Our goal is to develop our employees to have the highest technical and leadership capabilities in the industry. We focus on merit-based, long-term career development and are committed to maintaining a diverse workforce. We recruit talented people from around the world and provide them with formal training and a broad range of global experiences to develop them into the next generation of company leaders. Investing in our people creates a sustainable source of competitive advantage.

SUPERIOR CASH FLOW

Increase Efficiency Through Our Global Functional Organization ExxonMobil’s global functional organization is fundamental to our ongoing success. Developed over many years, it is built on the common standards, processes, and culture of the Corporation, and generates a unique advantage. Our organizational structure requires senior management involvement in all major decisions and ensures consistent global execution of our business processes. We continue to discover new ways to leverage and enhance the approach to deliver increased value.

Optimize Results Through Functional Diversity and Integration ExxonMobil’s business portfolio and level of global integration are unique in our industry. Our portfolio of assets provides advantages in scale, geographic diversity, and business mix, and mitigates risks that arise from changes in commodity prices, product margins, and business cycles. Through integration, we are able to capture new opportunities and deliver greater value than any of our businesses could achieve on a stand-alone basis. The combination of our global scale and integration across our businesses gives ExxonMobil a competitive advantage that is difficult to replicate.

DISCIPLINED INVESTMENT AND INDUSTRY-LEADING RETURNS

Invest with Discipline The energy industry is a long-term business that requires decisions to be made with a time horizon that is measured in decades and that spans multiple business cycles. Projects are tested over a wide range of economic scenarios to ensure that risks are properly identified, evaluated, and managed. This approach enables superior investment returns throughout the business cycle. Our proven project management system incorporates best practices developed around the world. Emphasis on the early phases of concept selection

and effective project execution results in investments that maximize resource and asset value. We complete a rigorous reappraisal of all major projects and incorporate learnings into future project planning and design, further strengthening our capabilities.

Differentiate with Proprietary Technology Technology is vital to meeting the world’s growing demand for energy. Technological innovation creates resource opportunities by delivering cost-effective solutions in challenging environments and enables the development of high-performance products and improved manufacturing processes. ExxonMobil has a long-standing commitment to fundamental research to develop and grow our technical capabilities and to deliver advantaged technologies for all of our businesses. We have a wide array of research programs designed to meet the needs identified in our functional businesses. Over the past five years, we have invested more than $4 billion in research and development. Our global functional organization enables rapid deployment of new technologies to ensure early value capture.

Maintain Financial Strength ExxonMobil’s financial position remains unparalleled in industry. In today’s challenging economic environment, this represents a unique competitive advantage. Moody’s and Standard & Poor’s recognize our superior financial strength by assigning the highest credit rating to our financial obligations. ExxonMobil is one of very few public companies that has maintained this credit rating consistently for decades. Our financial strength gives us the flexibility to pursue and finance attractive investment opportunities.

Corporate


FINANCIAL HIGHLIGHTS	2010		2009			2008			2007			2006
(millions of dollars, unless noted)
Sales and other operating revenue⁽¹⁾		370,125		301,500			459,579			390,328			365,467
Net income attributable to ExxonMobil		30,460		19,280			45,220			40,610			39,500
Cash flow from operations and asset sales⁽²⁾		51,674		29,983			65,710			56,206			52,366
Capital and exploration expenditures⁽²⁾		32,226		27,092			26,143			20,853			19,855
Cash dividends to ExxonMobil shareholders		8,498		8,023			8,058			7,621			7,628
Common stock purchases (gross)		13,093		19,703			35,734			31,822			29,558
Research and development costs		1,012		1,050			847			814			733
Cash and cash equivalents at year end⁽³⁾		7,825		10,693			31,437			33,981			28,244
Total assets at year end		302,510		233,323			228,052			242,082			219,015
Total debt at year end		15,014		9,605			9,425			9,566			8,347
ExxonMobil share of equity at year end		146,839		110,569			112,965			121,762			113,844
Average capital employed⁽²⁾		145,217		125,050			129,683			128,760			122,573
Share price at year end (dollars)		73.12		68.19			79.83			93.69			76.63
Market valuation at year end		364,035		322,329			397,239			504,220			438,990
Regular employees at year end (thousands)		83.6		80.7			79.9			80.8			82.1


KEY FINANCIAL RATIOS		2010		2009			2008			2007			2006
Earnings per common share (dollars)		6.24		3.99			8.70			7.31			6.64
Earnings per common share – assuming dilution (dollars)		6.22		3.98			8.66			7.26			6.60
Return on average capital employed⁽²⁾ (percent)		21.7		16.3			34.2			31.8			32.2
Earnings to average ExxonMobil share of equity (percent)		23.7		17.3			38.5			34.5			35.1
Debt to capital⁽⁴⁾ (percent)		9.0		7.7			7.4			7.1			6.6
Net debt to capital⁽⁵⁾ (percent)		4.5		(1.0	)		(23.0	)		(24.0	)		(20.4	)
Current assets to current liabilities (times)		0.94		1.06			1.47			1.47			1.55
Fixed charge coverage (times)		42.2		25.8			54.6			51.6			47.8


(1)		Sales and other operating revenue includes sales-based taxes of $28,547 million for 2010, $25,936 million for 2009, $34,508 million for 2008, $31,728 million for 2007, and $30,381 million for 2006.

(2)		See Frequently Used Terms on pages 98 through 101.

(3)		Excluding restricted cash of $628 million in 2010, and $4,604 million in 2006.

(4)		Debt includes short- and long-term debt. Capital includes short- and long-term debt and total equity.

(5)		Debt net of cash and cash equivalents, excluding restricted cash.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

ExxonMobil is proud to be a leader in providing reliable, affordable energy in a safe, secure, and environmentally responsible way. We are also proud of our ongoing efforts to identify and develop new technologies that enable us to be more competitive and efficient.

RESULTS & HIGHLIGHTS


Best-ever performance in workforce safety. Strong earnings of $30.5 billion, including record Chemical earnings. Annual dividend per share growth of 5 percent versus 2009, the 28th consecutive year of dividend per share increases. Total shareholder distributions of $19.7 billion. Industry-leading return on average capital employed of 22 percent. Completion of XTO Energy Inc. transaction. Total net production of liquids and natural gas available for sale of 4.4 million oil-equivalent barrels per day. Proved oil and gas reserve additions of 3.5 billion oil-equivalent barrels, replacing 211 percent of production, excluding asset sales. Completed new ultra-low sulfur diesel facilities at three refineries. Major expansion under way at the Singapore petrochemical plant.

Business Environment As events in 2010 made clear, the energy industry faces multiple risks and challenges. The Deepwater Horizon oil spill in the Gulf of Mexico highlighted the technical risk involved in energy exploration and production, and the vital importance of excellence in operations integrity and controls. While global economic recovery continues, concerns remain about the pace and scope of that growth. International oil companies like ExxonMobil face shifting government policies regarding access to energy resources, and changing U.S. environmental policies could greatly affect energy economics. Even in this uncertain business environment, ExxonMobil operates and manages risk successfully, confident in our business model. Our proven business model is driven by disciplined investment decisions, a long-term outlook on energy, relentless emphasis on operational excellence, and continuous innovation and technology leadership.

(1) See Frequently Used Terms on pages 98 through 101.

(2) Royal Dutch Shell, BP, and Chevron values are on a consistent basis with ExxonMobil, based on public information.

(3) Reflects data through December 31, 2010.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Meeting growing energy demand in a safe and environmentally responsible way is a key challenge of our time.

Ensuring reliable and affordable energy supplies to support human progress, safely and with minimum impact to the environment, is a key challenge facing not only ExxonMobil, but also governments and societies around the world. ExxonMobil’s The Outlook for Energy: A View to 2030, outlines our long-term forecast of supply and demand trends, which guides our investment decisions. We also share it publicly to encourage a better understanding of global energy systems and challenges.

GROWING ENERGY CHALLENGES

Key Conclusions Despite an uneven pace of economic recovery, global energy demand is likely to grow by about 35 percent from 2005 to 2030, even with significant gains in efficiency. Virtually all the growth in energy use will occur in developing countries, where demand will increase more than 70 percent, led by China and India.


The fastest growing major energy source will be natural gas, reflecting strong demand for clean-burning fuels to meet expanding electricity demand. By 2030, natural gas will displace coal as the second most prominent source of energy		By 2030, natural gas is projected to be the second largest energy source globally.
worldwide. Oil will remain the largest source of energy, with demand increasing approximately 20 percent, driven by rising transportation needs. Energy demand for transportation of all types will be up nearly 40 percent from 2005 to 2030, the result of growing commercial activity and personal vehicle use.

Meeting needs for reliable, affordable energy continues to require the wise and efficient use of energy. We anticipate efficiency gains will curb global energy demand by one-third in 2030 and contribute to significant progress in stemming the growth of energy-related carbon dioxide (CO₂) emissions, a component of greenhouse gas.

Keeping pace with global energy demand – including replacing supplies consumed each day and adding capacity to meet higher demand going forward – will require huge investments and pursuit of a diverse mix of economic sources of energy. According to the International Energy Agency, the investment required in new energy supply infrastructure is likely to be more than $1 trillion per year on average through 2035. At the same time, we must continue to advance technologies to handle increasing complexities of energy production and minimize the impact on the environment.

Global Energy Demand and Supply Increasing Through 2030, the global energy demand picture will be shaped by economic expansion and progress, particularly in non-OECD⁽¹⁾ countries, which will account for essentially all the growth in energy use. More than half of the growth in demand will be driven by increasing energy needs for power generation, making it the largest and fastest growing demand sector.


(1) OECD = Organization for Economic Cooperation and Development		Oil, natural gas, and coal will continue to meet most of the world’s needs, accounting for approximately 80 percent of demand. No other energy sources can match their availability, versatility, affordability, and scale. Oil will still account for the largest share, but natural gas will move into second place on very strong growth. From 2005 to 2030, global demand for natural gas will increase about 60 percent. Nuclear power will also grow significantly in many countries to help meet rising electricity demand. Wind, solar, and biofuels will grow most rapidly through 2030, at nearly 10 percent a year on average. However, starting from a small base, their contribution by 2030 will remain relatively small at about 2.5 percent of total energy. Global energy demand will grow by about 35 percent from 2005 to 2030, primarily in developing countries.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW





Natural gas will become increasingly prominent while other energy sources also grow.		Trends for energy-related CO₂ emissions through 2030 vary greatly between OECD and non-OECD countries.

Growing Global Energy Demand and CO₂ Emissions Energy-related carbon dioxide (CO₂) emissions are linked to the types and amounts of energy used globally. These emissions are likely to rise about 25 percent from 2005 to 2030. While substantial, this rate of increase is significantly lower than that projected for energy demand and reflects trends that are significantly different for OECD and non-OECD countries. Energy-related CO₂ emissions in non-OECD nations exceed those in the OECD by almost 40 percent today, and by 2030 are likely to be double those of the OECD countries. At the same time, emissions on a per capita basis will remain substantially higher in OECD countries, even though actual OECD emissions will decline significantly by 2030.

PROVIDING SOLUTIONS

Meeting Increasing Worldwide Needs for Liquid Fuels Oil is the world’s single largest energy source with its most prominent use being for transportation. Nearly all the world’s transportation runs on liquid fuels because they provide a large quantity of energy in small volumes, making them easy to transport and widely available. Liquid fuels will also remain important for meeting industrial and residential needs. By 2030, the total demand for liquids will exceed 100 million oil-equivalent barrels per day.

Meeting the global liquids demand in an economic and environmentally responsible manner is critically important. The world’s large resource base, coupled with continuing advances in technology, will facilitate meeting this demand. Still, it will require

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

operational excellence, deployment of advanced technologies, access to resources, and sound, reliable policies that foster timely investments and open trade.

Many of the world’s promising resources require advanced technologies to unlock potential supplies. Resources such as those existing in deepwater and oil sands will be increasingly important through 2030.

Natural Gas to Meet a Rising Share of Energy Needs Given its abundance and its properties as an efficient, clean-burning fuel, natural gas will meet a growing share of the world’s energy needs. In North America and Europe, natural gas contributes more than 20 percent of total energy, and its share will increase as gas demand grows by 25 to 30 percent. In Asia Pacific, natural gas is about 10 percent of total energy demand and will grow much more rapidly, nearly tripling by 2030 versus 2005.

An important supply development has been the expansion of unconventional natural gas, which is the result of recent improvements in technologies used to tap these hard-to-produce resources. This is particularly the case in the United States, where unconventional sources are expected to satisfy more than 50 percent of gas demand in 2030. We also anticipate growing supplies of liquefied natural gas (LNG) to meet growing demand, particularly in Europe and in Asia Pacific.

Sustained Innovation and Investments Remain Vital to Expanding Economic Options Helping expand access to modern energy and technology will remain critical to help people prosper in the decades ahead, with technology and the mix of economic energy supplies continuing to evolve. To provide solutions of the scale embodied by the Outlook for Energy, the world will need

Helping people prosper around the
world will require advanced technologies
and significant investments to pursue
all commercially viable energy solutions.

tremendous levels of investment, sustained over decades; an unwavering drive for innovation and new technology; and, policies that promote a level playing field for pursuing all commercially viable energy solutions. ExxonMobil is making enormous investments to provide effective energy solutions to help enable progress around the world.

UpClose: The Importance of Natural Gas

Growing demand for natural gas reflects its ability to serve as a reliable, affordable energy source for increasing power generation, and industrial and residential/commercial needs, while also mitigating impacts on the environment. ExxonMobil’s Outlook for Energy contains several projections that underscore the importance of natural gas.

A key driver for growth in natural gas is global demand for electricity, which is likely to rise by more than 80 percent from 2005 to 2030. This reflects economic progress and the fact that close to 1.4 billion people currently lack access to electricity. To help meet this tremendous need for power generation, natural gas is a particularly attractive fuel. It is abundant, and gas-fired power plants are based on proven technology, can be built quickly and economically, and will produce up to 60-percent fewer CO₂ emissions than coal-fired plants.

On the supply side, ExxonMobil views unconventional gas as a key resource for meeting the world’s energy and environmental needs. By 2030, global production of tight gas, shale gas, and other forms of unconventional gas is expected to be close to five times the level of 2005. Unconventional supplies will represent more than 15 percent of global natural gas production in 2030, compared to about 5 percent in 2005.

In addition, there is a large and growing market for liquefied natural gas (LNG), enabled by technologies that have expanded economic supply options. Expansion of LNG supplies will support a growing need for natural gas imports to meet rising demand in many markets, including the United States, Europe, and Asia Pacific.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Meeting the energy challenge requires effective risk management and a relentless focus on operational excellence.

Risk is a part of any business. The energy industry faces a unique set of risks. There are technical, financial, and geopolitical risks as well as risks to safety, security, health, and the environment. The extent to which an organization identifies and successfully manages risks will define its business success.

ExxonMobil believes that our ability to consistently deliver strong returns to shareholders is a direct result of our ability to effectively manage risk.

Risk cannot be eliminated, but it can be managed. ExxonMobil manages risk through a capable and committed workforce with clear accountability, well-developed and clearly defined policies and procedures, high standards of design, rigorously applied management systems, employee and contractor training, and a systematic approach to assessing performance that drives continuous improvement.

MANAGING OPERATIONAL RISK

Operations Integrity Management System (OIMS) As events in 2010 made clear, the energy industry faces multiple risks and challenges. The Deepwater Horizon oil spill in the Gulf of Mexico highlighted the technical risk involved in energy exploration and production. The incident shook public confidence in our industry and spurred governments and consumers to ask what the industry can do to ensure that meeting future energy needs does not come at the expense of safety or the environment.

By focusing on the integrity of our operations, ExxonMobil improves safety and environmental performance, and maximizes the return to shareholders.

ExxonMobil asked itself a similar question after the 1989 Valdez oil spill. We realized that just a commitment to safety and operational excellence was not enough. What was also needed was a system that put commitment into action: a global framework that put safety first and treated safety, security, health and environmental performance with the same discipline, structure, and accountability that we applied to our operations.

ExxonMobil today employs such a framework: our Operations Integrity Management System (OIMS). OIMS is the cornerstone of our commitment to managing risks to safety, security, health, and the environment. It guides the activities of each of our employees and contractors around the world.

OIMS is a rigorous, 11-element system designed to identify hazards and manage risks. It covers: design,

(1) Excludes XTO Energy Inc. data.
(2) Employee safety data from participating American Petroleum Institute
companies (2010 industry data not available at time of publication).

construction and maintenance of facilities; preparation of employees and communities for natural disaster or other incidents; and thorough investigations into accidents and safety incidents.

Through OIMS, ExxonMobil has achieved industry-leading safety performance. Our lost-time incident rates have been significantly reduced, and operating efficiencies have improved. Risks to the environment have been reduced, with a sharp decline in spills and continuing reduction in emissions. By focusing on the integrity of our operations, ExxonMobil improves safety and environmental performance, and maximizes the return to shareholders.

OIMS guides the activities of each of our more than 80,000 employees, as well as our contractors around the world. It is embedded into everyday work processes at all levels. Through OIMS, we achieved best-ever lost-time incident rates in 2010.

ADDRESSING CLIMATE CHANGE RISK

Reducing Greenhouse Gas Emissions The risk of climate change is important to the environment, the world economies, and to ExxonMobil’s business. Addressing this risk, while still providing reliable, affordable energy to meet growing demand, is the global challenge that shapes ExxonMobil’s activities and investments.

Since 2005, we have invested $1.6 billion in activities that improve our energy efficiency and reduce greenhouse gas (GHG) emissions.

ExxonMobil has substantially reduced emissions from our manufacturing operations. We remain on track to achieve our goal of improving energy efficiency across our worldwide manufacturing operations by at least 10 percent between 2002 and 2012 by applying our Global Energy Management System.

ExxonMobil has also made significant reductions in flaring and increases in cogeneration. We have invested more than $5 billion in gas utilization and commercialization projects to reduce natural gas flaring. Our hydrocarbon flaring is down almost 60 percent from levels of only a few years ago. With cogeneration, ExxonMobil can produce electricity for our operations with less GHG emissions than conventional power generation. ExxonMobil has interests in about 4.9 gigawatts of cogeneration capacity in over 100 individual installations at more than 30 locations around the world. We plan to increase our cogeneration capacity to more than 5 gigawatts in the next few years.

As a result of these investments, ExxonMobil has reduced costs, improved operational reliability, and reduced our GHG emissions by more than 11 million tonnes in 2010 compared to 2005.

ExxonMobil has also been active in developing and applying carbon capture and storage (CCS) technology to safely and effectively capture, transport, and store carbon dioxide (CO₂), a component of greenhouse gas, in underground geologic formations. In 2010, we captured approximately 5 million tonnes of CO₂ for underground injection in our natural gas operations in Wyoming in the United States and in our equity interest in the Sleipner field in Norway. CCS is a promising technology, and ExxonMobil has ongoing research to find breakthroughs to reduce the high costs of capturing CO₂.

In addition, because natural gas has lower CO₂ emissions per unit of energy, our substantial natural gas portfolio has the potential to help reduce GHG emissions while meeting the world’s growing energy needs. Also, our significant research program on algae biofuels could provide GHG reductions since algae consume CO₂. We are also developing technologies that help consumers use energy more efficiently.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Meeting the energy challenge requires world-class people, technology leadership, and financial strength.

ExxonMobil is committed to constant innovation because the world’s growing and evolving energy needs demand nothing less. This commitment, combined with our talented people and financial strength, is a powerful advantage in meeting the energy challenge.

EMPLOYING WORLD-CLASS PEOPLE

One reason for ExxonMobil’s success is our ability to attract and retain the brightest minds. We employ more than 16,000 scientists and engineers, more than 1000 of them with PhDs. Their expertise is not only in geology, chemistry, and physics, but also oceanography, paleontology, and microbiology, as well as computer, environmental, and medical science.

Another advantage is how we integrate our research and development organizations within our businesses, resulting in better collaboration between researchers and the businesses that can apply those technologies.

The men and women of ExxonMobil, backed by our industry-leading investments of more than $1 billion annually in research, development, and technology application, are developing new technologies that will improve our ability to safely and efficiently find and deliver more energy to the world.

DEVELOPING AND APPLYING TECHNOLOGY

ExxonMobil is committed to constant innovation to improve the supply of reliable, affordable energy in a safe and environmentally responsible manner. Over time, breakthrough technologies become the industry standard, and what was once considered an unconventional energy source becomes mainstream. ExxonMobil’s sustained commitment to technology is a competitive advantage. For example, the Arctic region and unconventional gas both hold tremendous energy potential. Accessing and producing these resources will require a broad suite of new technologies, from ice management in arctic environments, to enhanced imaging to identify optimum development locations in shale gas. As a technology leader, ExxonMobil is well-positioned to develop these challenging resources.

In today’s challenging energy industry,
a commitment to innovation is essential.
ExxonMobil leads industry in ongoing
investment in technology.

We are committed to technology across each of our core business functions, allowing us to consistently bring innovation to the forefront to deliver maximum return on investment.

Some of our successes include:

Upstream In the Upstream, we continue to build on the seismic and reservoir modeling technologies that we pioneered, which today enable us to identify new resource opportunities, drill more accurately, and improve recovery.

Downstream The Downstream business uses our advanced Molecule Management technology to run lower-cost crudes, maximize the value of every hydrocarbon molecule, and optimize overall refinery utilization.

Chemical Our Chemical business has developed technologies that can make vehicles more fuel efficient, including advanced polymers that help tires maintain proper inflation, lightweight plastics for automotive parts, and basestocks for advanced lubricants.

LEVERAGING FINANCIAL STRENGTH

ExxonMobil’s financial position remains unparalleled in industry. In today’s challenging economic environment, this represents a unique competitive advantage. Moody’s and Standard & Poor’s both recognize our superior financial strength by assigning the highest credit rating to our financial obligations. ExxonMobil is one of very few public companies that has maintained this credit rating consistently for decades. Our financial strength gives us the flexibility to pursue and finance attractive investment opportunities throughout the business cycle. In 2010, ExxonMobil invested $32.2 billion to develop new projects to help meet growing global energy demand.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Shareholder Information

ExxonMobil’s core objective is to deliver long-term growth in shareholder value. Over the past five years, we have distributed over $154 billion to our shareholders through quarterly dividend payments and share purchases to reduce shares outstanding. In 2010, our total shareholder distributions were $20 billion, including $11 billion of share purchases.

In 2010, ExxonMobil raised annual dividends to our shareholders to $1.74 per share, an increase of 5 percent versus the previous year. We have paid a dividend each year for more than a century and have increased annual dividends per share in each of the last 28 years.

ExxonMobil reduced the number of shares outstanding by 19 percent over the last five years, net of shares issued for XTO Energy Inc., through our flexible share purchase program. Reducing shares outstanding increases the percent ownership of the company that each remaining share represents, and contributes to increased earnings and cash flow per share.

DIVIDEND AND SHAREHOLDER RETURN INFORMATION


	2010		2009			2008			2007		2006
Earnings per common share (dollars)		6.24		3.99			8.70			7.31		6.64
Earnings per common share – assuming dilution (dollars)		6.22		3.98			8.66			7.26		6.60

Dividends per common share (dollars)
First quarter		0.42		0.40			0.35			0.32		0.32
Second quarter		0.44		0.42			0.40			0.35		0.32
Third quarter		0.44		0.42			0.40			0.35		0.32
Fourth quarter		0.44		0.42			0.40			0.35		0.32

Total		1.74		1.66			1.55			1.37		1.28

Dividends per share growth (annual percent)		4.8		7.1			13.1			7.0		12.3

Number of common shares outstanding (millions)
Average		4,885		4,832			5,194			5,557		5,948
Average – assuming dilution		4,897		4,848			5,221			5,594		5,987
Year end		4,979		4,727			4,976			5,382		5,729

Cash dividends paid on common stock (millions of dollars)		8,498		8,023			8,058			7,621		7,628
Cash dividends paid to earnings (percent)		28		42			18			19		19
Cash dividends paid to cash flow⁽¹⁾ (percent)		18		28			13			15		15

Total return to shareholders (annual percent)		10.1		(12.6	)		(13.2	)		24.3		39.2

Market quotations for common stock (dollars)
High		73.69		82.73			96.12			95.27		79.00
Low		55.94		61.86			56.51			69.02		56.42
Average daily close		64.99		70.95			82.68			83.23		65.35
Year-end close		73.12		68.19			79.83			93.69		76.63


(1)		Net cash provided by operating activities.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Results

ExxonMobil’s business model combines long-term perspective, operational excellence, superior cash flow, and disciplined capital investment to deliver value to our shareholders. Our business model, together with our proven strategies, is key to achieving sustained, outstanding performance in all aspects of our business.




	(1) Net income attributable to ExxonMobil.		(1) Net cash from operating and investing activities, excluding changes in restricted cash and cash equivalents, and marketable securities (see page 23).

	ExxonMobil delivered earnings of $30.5 billion in 2010, which included record results in our Chemical business. We continue to leverage our strong integrated business model for earnings and efficiency advantages.		Strong cash flow from operations and asset sales is more than sufficient to fund a growing level of investments in the business. We continue to generate strong operating cash flows from our highly efficient capital base.

ExxonMobil’s integrated business model allows us to maximize shareholder value across a diverse portfolio.





	(1) See Frequently Used Terms on pages 98 through 101.

	ExxonMobil’s capital and exploration expenditures support a diverse mix of projects. Our financial strength allows us to continue investing in new technology and attractive projects to bring affordable energy to the world.		ExxonMobil’s business portfolio provides advantages in scale, geographic diversity, and business mix. The strategic diversity of our assets, combined with our unique level of global integration, differentiates us and allows us to maximize shareholder value.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

FUNCTIONAL EARNINGS⁽¹⁾

2010 Quarters

(millions of dollars)

First

Second

Third

Fourth

2010

2009

2008

2007

2006

Earnings (U.S. GAAP)

Upstream

United States

1,091

865

999

1,317

4,272

2,893

6,243

4,870

5,168

Non-U.S.

4,723

4,471

4,468

6,163

19,825

14,214

29,159

21,627

21,062

Total

5,814

5,336

5,467

7,480

24,097

17,107

35,402

26,497

26,230

Downstream

United States

(60

)

440

164

226

770

(153

)

1,649

4,120

4,250

Non-U.S.

780

996

924

2,797

1,934

6,502

5,453

4,204

Total

1,220

1,160

1,150

3,567

1,781

8,151

9,573

8,454

Chemical

United States

539

685

676

522

2,422

769

724

1,181

1,360

Non-U.S.

710

683

553

545

2,491

1,540

2,233

3,382

3,022

Total

1,249

1,368

1,229

1,067

4,913

2,309

2,957

4,563

4,382

Corporate and financing

(800

)

(364

)

(506

)

(447

)

(2,117

)

(1,917

)

(1,290

)

(23

)

434

Net income attributable to ExxonMobil (U.S. GAAP)

6,300

7,560

7,350

9,250

30,460

19,280

45,220

40,610

39,500

Earnings per common share⁽²⁾ (dollars)

1.33

1.61

1.44

1.86

6.24

3.99

8.70

7.31

6.64

Earnings per common share – assuming dilution⁽²⁾ (dollars)

1.33

1.60

1.44

1.85

6.22

3.98

8.66

7.26

6.60

Special Items

Upstream

United States

–

Non-U.S.

–

1,620

–

Total

–

1,620

–

Downstream

United States

–

Non-U.S.

–

Total

–

Chemical

United States

–

Non-U.S.

–

Total

–

Corporate and financing

–

(140

)

(460

)

–

410

Corporate total

–

(140

)

1,160

–

410

Earnings Excluding Special Items⁽³⁾

Upstream

United States

1,091

865

999

1,317

4,272

2,893

6,243

4,870

5,168

Non-U.S.

4,723

4,471

4,468

6,163

19,825

14,214

27,539

21,627

21,062

Total

5,814

5,336

5,467

7,480

24,097

17,107

33,782

26,497

26,230

Downstream

United States

(60

)

440

164

226

770

(153

)

1,649

4,120

4,250

Non-U.S.

780

996

924

2,797

1,934

6,502

5,453

4,204

Total

1,220

1,160

1,150

3,567

1,781

8,151

9,573

8,454

Chemical

United States

539

685

676

522

2,422

769

724

1,181

1,360

Non-U.S.

710

683

553

545

2,491

1,540

2,233

3,382

3,022

Total

1,249

1,368

1,229

1,067

4,913

2,309

2,957

4,563

4,382

Corporate and financing

(800

)

(364

)

(506

)

(447

)

(2,117

)

(1,777

)

(830

)

(23

)

Corporate total

6,300

7,560

7,350

9,250

30,460

19,420

44,060

40,610

39,090

Earnings per common share⁽²⁾ (dollars)

1.33

1.61

1.44

1.86

6.24

4.02

8.48

7.31

6.57

Earnings per common share – assuming dilution⁽²⁾ (dollars)

1.33

1.60

1.44

1.85

6.22

4.01

8.44

7.26

6.53


(1)		Total corporate earnings means net income attributable to ExxonMobil (U.S. GAAP) from the consolidated income statement. Unless indicated, references to earnings, special items, Upstream, Downstream, Chemical, and Corporate and Financing segment earnings, and earnings per share are ExxonMobil’s share after excluding amounts attributable to noncontrolling interests.

(2)		Computed using the average number of shares outstanding during each period. The sum of the four quarters may not add to the full year.

(3)		See Frequently Used Terms on pages 98 through 101.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

RETURN ON AVERAGE CAPITAL EMPLOYED⁽¹⁾ BY BUSINESS


(percent)	2010		2009			2008		2007		2006
Upstream
United States		12.2		18.2			42.6		34.7		37.1
Non-U.S.		29.0		24.8			56.7		43.7		47.9
Total		23.3		23.4			53.6		41.7		45.3

Downstream
United States		12.5		(2.1	)		23.7		65.1		65.8
Non-U.S.		15.6		10.9			34.8		28.7		24.5
Total		14.8		7.1			31.8		37.8		35.8

Chemical
United States		53.0		17.6			16.0		24.9		27.7
Non-U.S.		17.6		12.6			22.4		39.0		36.5
Total		26.3		13.9			20.4		34.0		33.2

Corporate and financing		N.A.		N.A.			N.A.		N.A.		N.A.

Corporate total		21.7		16.3			34.2		31.8		32.2


(1)		Capital employed consists of ExxonMobil’s share of equity and consolidated debt, including ExxonMobil’s share of amounts applicable to equity companies. See Frequently Used Terms on pages 98 through 101.

AVERAGE CAPITAL EMPLOYED⁽¹⁾ BY BUSINESS


(millions of dollars)	2010			2009		2008		2007		2006
Upstream
United States		34,969			15,865		14,651		14,026		13,940
Non-U.S.		68,318			57,336		51,413		49,539		43,931
Total		103,287			73,201		66,064		63,565		57,871

Downstream
United States		6,154			7,306		6,963		6,331		6,456
Non-U.S.		17,976			17,793		18,664		18,983		17,172
Total		24,130			25,099		25,627		25,314		23,628

Chemical
United States		4,566			4,370		4,535		4,748		4,911
Non-U.S.		14,114			12,190		9,990		8,682		8,272
Total		18,680			16,560		14,525		13,430		13,183

Corporate and financing		(880	)		10,190		23,467		26,451		27,891

Corporate total		145,217			125,050		129,683		128,760		122,573

Average capital employed applicable to equity companies included above		30,524			27,684		25,651		24,267		22,106


(1)		Average capital employed is the average of beginning- and end-of-year business segment capital employed, including ExxonMobil’s share of amounts applicable to equity companies. See Frequently Used Terms on pages 98 through 101.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

CAPITAL AND EXPLORATION EXPENDITURES⁽¹⁾


(millions of dollars)	2010		2009		2008		2007		2006

Upstream
Exploration
United States		1,607		735		734		415		425
Non-U.S.		2,514		2,983		2,137		1,494		1,619
Total		4,121		3,718		2,871		1,909		2,044

Production⁽²⁾
United States		4,742		2,850		2,600		1,792		2,058
Non-U.S.		18,214		13,877		14,011		11,913		12,059
Total		22,956		16,727		16,611		13,705		14,117

Power and Coal
United States		–		–		–		5		3
Non-U.S.		242		259		252		105		67
Total		242		259		252		110		70

Total Upstream		27,319		20,704		19,734		15,724		16,231


Downstream
Refining
United States		833		1,300		1,430		906		559
Non-U.S.		1,000		1,146		1,248		1,267		1,051
Total		1,833		2,446		2,678		2,173		1,610

Marketing
United States		98		171		176		201		233
Non-U.S.		520		536		638		876		852
Total		618		707		814		1,077		1,085

Pipeline/Marine
United States		51		40		30		21		32
Non-U.S.		3		3		7		32		2
Total		54		43		37		53		34

Total Downstream		2,505		3,196		3,529		3,303		2,729


Chemical
United States		279		319		441		360		280
Non-U.S.		1,936		2,829		2,378		1,422		476

Total Chemical		2,215		3,148		2,819		1,782		756


Other
United States		187		44		61		44		130
Non-U.S.		–		–		–		–		9

Total other		187		44		61		44		139

Total capital and exploration expenditures		32,226		27,092		26,143		20,853		19,855

(1) See Frequently Used Terms on pages 98 through 101.

(2) Including related transportation.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

TOTAL CAPITAL AND EXPLORATION EXPENDITURES BY GEOGRAPHY


(millions of dollars)	2010		2009		2008		2007		2006

United States		7,797		5,459		5,472		3,744		3,720
Canada/Latin America		5,732		3,448		1,926		1,522		1,862
Europe		3,901		3,251		3,727		4,042		3,721
Africa		4,915		6,182		5,422		3,639		4,019
Asia		6,693		7,535		8,845		7,479		6,168
Australia/Oceania		3,188		1,217		751		427		365

Total worldwide		32,226		27,092		26,143		20,853		19,855

DISTRIBUTION OF CAPITAL AND EXPLORATION EXPENDITURES


(millions of dollars)	2010		2009		2008		2007		2006

Consolidated Companies’ Expenditures
Capital expenditures		27,343		22,441		19,841		15,242		15,361
Exploration costs charged to expense
United States		283		219		189		280		243
Non-U.S.		1,855		1,795		1,252		1,177		925
Depreciation on support equipment⁽¹⁾		6		7		10		12		13
Total exploration expenses		2,144		2,021		1,451		1,469		1,181

Total consolidated companies’ capital and exploration expenditures (excluding depreciation on support equipment)		29,481		24,455		21,282		16,699		16,529
ExxonMobil’s Share of Non-Consolidated Companies’ Expenditures
Capital expenditures		2,720		2,624		4,845		4,122		3,315
Exploration costs charged to expense		25		13		16		32		11
Total non-consolidated companies’ capital and exploration expenditures		2,745		2,637		4,861		4,154		3,326

Total capital and exploration expenditures		32,226		27,092		26,143		20,853		19,855

(1) Not included as part of total capital and exploration expenditures, but included as part of exploration expenses, including dry holes, in the Summary Statement of Income, page 22.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

NET INVESTMENT IN PROPERTY, PLANT AND EQUIPMENT AT YEAR END


(millions of dollars)	2010		2009		2008		2007		2006

Upstream
United States		69,003		19,601		17,920		16,714		16,467
Non-U.S.		79,149		68,718		55,493		56,810		51,943
Total		148,152		88,319		73,413		73,524		68,410

Downstream
United States		10,585		11,013		10,492		9,705		9,320
Non-U.S.		19,510		19,486		18,762		20,443		19,598
Total		30,095		30,499		29,254		30,148		28,918

Chemical
United States		4,068		4,274		4,396		4,448		4,553
Non-U.S.		10,187		9,237		7,034		5,623		4,766
Total		14,255		13,511		11,430		10,071		9,319

Other		7,046		6,787		7,249		7,126		7,040

Total net investment		199,548		139,116		121,346		120,869		113,687

DEPRECIATION AND DEPLETION EXPENSES


(millions of dollars)	2010		2009		2008		2007		2006

Upstream
United States		3,506		1,768		1,391		1,469		1,263
Non-U.S.		7,574		6,376		7,266		7,126		6,482
Total		11,080		8,144		8,657		8,595		7,745

Downstream
United States		681		687		656		639		632
Non-U.S.		1,565		1,665		1,672		1,662		1,605
Total		2,246		2,352		2,328		2,301		2,237

Chemical
United States		421		400		410		405		427
Non-U.S.		432		457		422		418		473
Total		853		857		832		823		900

Other		581		564		562		531		534

Total depreciation and depletion expenses		14,760		11,917		12,379		12,250		11,416

OPERATING COSTS⁽¹⁾


(millions of dollars)	2010		2009		2008		2007		2006

Production and manufacturing expenses		35,792		33,027		37,905		31,885		29,528
Selling, general, and administrative		14,683		14,735		15,873		14,890		14,273
Depreciation and depletion		14,760		11,917		12,379		12,250		11,416
Exploration		2,144		2,021		1,451		1,469		1,181

Subtotal		67,379		61,700		67,608		60,494		56,398
ExxonMobil’s share of equity company expenses		9,049		6,670		7,204		5,619		4,947

Total operating costs		76,428		68,370		74,812		66,113		61,345

(1) See Frequently Used Terms on pages 98 through 101.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

SUMMARY BALANCE SHEET AT YEAR END


(millions of dollars)	2010			2009			2008			2007			2006

Assets
Current assets
Cash and cash equivalents		7,825			10,693			31,437			33,981			28,244
Cash and cash equivalents – restricted		628			–			–			–			4,604
Marketable securities		2			169			570			519			–
Notes and accounts receivable, less estimated doubtful amounts		32,284			27,645			24,702			36,450			28,942
Inventories
Crude oil, products and merchandise		9,852			8,718			9,331			8,863			8,979
Materials and supplies		3,124			2,835			2,315			2,226			1,735
Other current assets		5,269			5,175			3,911			3,924			3,273

Total current assets		58,984			55,235			72,266			85,963			75,777

Investments, advances and long-term receivables		35,338			31,665			28,556			28,194			23,237
Property, plant and equipment, at cost, less accumulated depreciation and depletion		199,548			139,116			121,346			120,869			113,687
Other assets, including intangibles, net		8,640			7,307			5,884			7,056			6,314

Total assets		302,510			233,323			228,052			242,082			219,015


Liabilities
Current liabilities
Notes and loans payable		2,787			2,476			2,400			2,383			1,702
Accounts payable and accrued liabilities		50,034			41,275			36,643			45,275			39,082
Income taxes payable		9,812			8,310			10,057			10,654			8,033

Total current liabilities		62,633			52,061			49,100			58,312			48,817

Long-term debt		12,227			7,129			7,025			7,183			6,645
Postretirement benefits reserves		19,367			17,942			20,729			13,278			13,931
Deferred income tax liabilities		35,150			23,148			19,726			22,899			20,851
Other long-term obligations		20,454			17,651			13,949			14,366			11,123

Total liabilities		149,831			117,931			110,529			116,038			101,367

Commitments and contingencies	See footnote 1

Equity
Common stock without par value		9,371			5,503			5,314			4,933			4,786
Earnings reinvested		298,899			276,937			265,680			228,518			195,207
Accumulated other comprehensive income
Cumulative foreign exchange translation adjustment		5,011			4,402			1,146			7,972			3,733
Postretirement benefits reserves adjustment		(9,889	)		(9,863	)		(11,077	)		(5,983	)		(6,495	)
Unrealized gain/(loss) on cash flow hedges		55			–			–			–			–
Common stock held in treasury		(156,608	)		(166,410	)		(148,098	)		(113,678	)		(83,387	)

ExxonMobil share of equity		146,839			110,569			112,965			121,762			113,844

Noncontrolling interests		5,840			4,823			4,558			4,282			3,804

Total equity		152,679			115,392			117,523			126,044			117,648

Total liabilities and equity		302,510			233,323			228,052			242,082			219,015

(1) For more information, please refer to Note 15 in the Financial Section of ExxonMobil’s 2010 Form 10-K.

The information in the Summary Statement of Income (for 2008 to 2010), the Summary Balance Sheet (for 2009 and 2010), and the Summary Statement of Cash Flows (for 2008 to 2010), shown on pages 21 through 23, corresponds to the information in the Consolidated Statement of Income, Consolidated Balance Sheet, and the Consolidated Statement of Cash Flows in the financial statements of ExxonMobil’s 2010 Form 10-K. For complete consolidated financial statements, including notes, please refer to the Financial Section of ExxonMobil’s 2010 Form 10-K. See also Management’s Discussion and Analysis of Financial Condition and Results of Operations and other information in the Financial Section of the 2010 Form 10-K.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

SUMMARY STATEMENT OF INCOME


(millions of dollars)	2010		2009		2008		2007		2006

Revenues and Other Income
Sales and other operating revenue⁽¹⁾		370,125		301,500		459,579		390,328		365,467
Income from equity affiliates		10,677		7,143		11,081		8,901		6,985
Other income⁽²⁾		2,419		1,943		6,699		5,323		5,183

Total revenues and other income		383,221		310,586		477,359		404,552		377,635


Costs and Other Deductions
Crude oil and product purchases		197,959		152,806		249,454		199,498		182,546
Production and manufacturing expenses		35,792		33,027		37,905		31,885		29,528
Selling, general, and administrative expenses		14,683		14,735		15,873		14,890		14,273
Depreciation and depletion		14,760		11,917		12,379		12,250		11,416
Exploration expenses, including dry holes		2,144		2,021		1,451		1,469		1,181
Interest expense		259		548		673		400		654
Sales-based taxes⁽¹⁾		28,547		25,936		34,508		31,728		30,381
Other taxes and duties		36,118		34,819		41,719		40,953		39,203

Total costs and other deductions		330,262		275,809		393,962		333,073		309,182

Income before income taxes		52,959		34,777		83,397		71,479		68,453
Income taxes		21,561		15,119		36,530		29,864		27,902

Net income including noncontrolling interests		31,398		19,658		46,867		41,615		40,551

Net income attributable to noncontrolling interests		938		378		1,647		1,005		1,051

Net income attributable to ExxonMobil		30,460		19,280		45,220		40,610		39,500


Earnings per Common Share (dollars)		6.24		3.99		8.70		7.31		6.64

Earnings per Common Share – Assuming Dilution (dollars)		6.22		3.98		8.66		7.26		6.60


(1)		Sales and other operating revenue includes sales-based taxes of $28,547 million for 2010, $25,936 million for 2009, $34,508 million for 2008, $31,728 million for 2007, and $30,381 million for 2006.

(2)		Other income for 2008 includes a $62 million gain from the sale of a non-U.S. investment and a related $143 million foreign exchange loss.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

SUMMARY STATEMENT OF CASH FLOWS


(millions of dollars)	2010			2009			2008			2007			2006

Cash Flows from Operating Activities
Net income including noncontrolling interests		31,398			19,658			46,867			41,615			40,551
Adjustments for noncash transactions
Depreciation and depletion		14,760			11,917			12,379			12,250			11,416
Deferred income tax charges/(credits)		(1,135	)		–			1,399			124			1,717
Postretirement benefits expense in excess of/(less than) net payments		1,700			(1,722	)		57			(1,314	)		(1,787	)
Other long-term obligation provisions in excess of/(less than) payments		160			731			(63	)		1,065			(666	)
Dividends received greater than/(less than) equity in current earnings of equity companies		(596	)		(483	)		921			(714	)		(579	)
Changes in operational working capital, excluding cash and debt
Reduction/(increase) – Notes and accounts receivable		(5,863	)		(3,170	)		8,641			(5,441	)		(181	)
– Inventories		(1,148	)		459			(1,285	)		72			(1,057	)
– Other current assets		913			132			(509	)		280			(385	)
Increase/(reduction) – Accounts and other payables		9,943			1,420			(5,415	)		6,228			1,160
Net (gain) on asset sales		(1,401	)		(488	)		(3,757	)		(2,217	)		(1,531	)
All other items – net		(318	)		(16	)		490			54			628

Net cash provided by operating activities		48,413			28,438			59,725			52,002			49,286


Cash Flows from Investing Activities
Additions to property, plant and equipment		(26,871	)		(22,491	)		(19,318	)		(15,387	)		(15,462	)
Sales of subsidiaries, investments, and property, plant and equipment		3,261			1,545			5,985			4,204			3,080
Decrease/(increase) in restricted cash and cash equivalents		(628	)		–			–			4,604			–
Additional investments and advances		(1,239	)		(2,752	)		(2,495	)		(3,038	)		(2,604	)
Collection of advances		1,133			724			574			391			756
Additions to marketable securities		(15	)		(16	)		(2,113	)		(646	)		–
Sales of marketable securities		155			571			1,868			144			–

Net cash used in investing activities		(24,204	)		(22,419	)		(15,499	)		(9,728	)		(14,230	)


Cash Flows from Financing Activities
Additions to long-term debt		1,143			225			79			592			318
Reductions in long-term debt		(6,224	)		(68	)		(192	)		(209	)		(33	)
Additions to short-term debt		598			1,336			1,067			1,211			334
Reductions in short-term debt		(2,436	)		(1,575	)		(1,624	)		(809	)		(451	)
Additions/(reductions) in debt with three months or less maturity		709			(71	)		143			(187	)		(95	)
Cash dividends to ExxonMobil shareholders		(8,498	)		(8,023	)		(8,058	)		(7,621	)		(7,628	)
Cash dividends to noncontrolling interests		(281	)		(280	)		(375	)		(289	)		(239	)
Changes in noncontrolling interests		(7	)		(113	)		(419	)		(659	)		(493	)
Tax benefits related to stock-based awards		122			237			333			369			462
Common stock acquired		(13,093	)		(19,703	)		(35,734	)		(31,822	)		(29,558	)
Common stock sold		1,043			752			753			1,079			1,173

Net cash used in financing activities		(26,924	)		(27,283	)		(44,027	)		(38,345	)		(36,210	)

Effects of exchange rate changes on cash		(153	)		520			(2,743	)		1,808			727

Increase/(decrease) in cash and cash equivalents		(2,868	)		(20,744	)		(2,544	)		5,737			(427	)
Cash and cash equivalents at beginning of year		10,693			31,437			33,981			28,244			28,671

Cash and cash equivalents at end of year		7,825			10,693			31,437			33,981			28,244

Non-Cash Transactions
The Corporation acquired all the outstanding equity of XTO Energy Inc. in an all-stock transaction valued at $24,659 million in 2010 (see Note 19 in the Financial Section of ExxonMobil’s 2010 Form 10-K).

COMPETITIVE ADVANTAGES

Balanced Portfolio Quality • We identify, selectively pursue, and capture the highest-quality resources. The quality, size, and diversity of ExxonMobil’s resource base and project inventory support a strong long-term outlook.

Disciplined Investing • Our focus on disciplined, selective investment from initial resource capture, through project development, to ongoing operations underpins our ability to deliver superior returns. The combination of our technical, project, and commercial expertise ensures we develop our resources most efficiently and effectively.

High-Impact Technologies • We employ high-impact technologies in exploration, reservoir modeling, project development, and production to ensure we maximize resource value with the optimum life-cycle development.

Operational Excellence • We explore, develop, produce, and market oil and gas using globally deployed management systems which ensure consistent application of the highest operational standards, effectively managing risk in all aspects of our business.

Global Integration • The global functional Upstream companies work with the Downstream and Chemical businesses to identify and deliver integrated solutions that maximize resource value.

Upstream

BUSINESS OVERVIEW

In 2010, in addition to delivering strong operating results, ExxonMobil Upstream continued to make significant investments to develop our diverse project portfolio and position us to deliver the energy required for the future.

With our partner Qatar Petroleum, we completed the Qatar liquefied natural gas (LNG) value chain with the start-up of RasGas Train 7 and initial commissioning and first gas send-out at the Golden Pass LNG receiving terminal. These projects are the latest in a series of world-scale integrated projects that ensure gas from the North Field of Qatar can be competitively delivered to markets around the world.

In the first quarter of 2010, ExxonMobil signed an agreement for the redevelopment and expansion of the West Qurna (Phase I) field in Iraq. Working with our partners, we commenced drilling, wellwork, and facility modification activities to begin ramp-up of production.

In June 2010, ExxonMobil became the largest natural gas producer in the United States following the merger with XTO Energy Inc. Combining these assets with our existing acreage position created a premier global unconventional gas portfolio. Through the remainder of the year, we progressed integration activities by transferring best practices across our operations and applying XTO’s expertise across our global unconventional portfolio.

In addition to these achievements, ExxonMobil has continued to capture new opportunities to add to our resource base, including the acquiring of unconventional assets in multiple North American shale gas locations. We also continued our active exploration around the globe. Our balanced exploration program is designed to test new high-potential exploration areas, further explore emerging unconventional opportunities, and continue to add resources through ongoing activity in established areas.

Overall, our Upstream business continues to effectively manage the safety, environmental, technical, financial, and geopolitical risks of our business, while delivering significant long-term value for our shareholders.


UPSTREAM STATISTICAL RECAP	2010		2009		2008		2007		2006
Earnings (millions of dollars)		24,097		17,107		35,402		26,497		26,230
Liquids production (net, thousands of barrels per day)		2,422		2,387		2,405		2,616		2,681
Natural gas production available for sale (net, millions of cubic feet per day)		12,148		9,273		9,095		9,384		9,334
Oil-equivalent production (net, thousands of barrels per day)		4,447		3,932		3,921		4,180		4,237
Proved reserves replacement⁽¹⁾⁽²⁾ (percent)		211		100		143		107		135
Resource additions⁽²⁾ (millions of oil-equivalent barrels)		14,580		2,860		2,230		2,010		4,270
Average capital employed⁽²⁾ (millions of dollars)		103,287		73,201		66,064		63,565		57,871
Return on average capital employed⁽²⁾ (percent)		23.3		23.4		53.6		41.7		45.3
Capital and exploration expenditures⁽²⁾ (millions of dollars)		27,319		20,704		19,734		15,724		16,231


(1)		Proved reserves exclude asset sales and the 2007 Venezuela expropriation. Includes non-consolidated interests and Canadian oil sands.

(2)		See Frequently Used Terms on pages 98 through 101.

Note: Unless otherwise stated, production rates, project capacities, and acreage values referred to on pages 24 through 61 are gross.

References to U.S. unconventional activities on pages 43 through 44 reflect the full year of 2010 activity for well count and gross-operated production.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Our 2010 Upstream results were underpinned by safety and environmental performance improvements, high reliability of our facilities, strong operating and capital spending discipline, and significant production volume growth.

RESULTS & HIGHLIGHTS

Best-ever workforce safety performance.

Earnings were $24.1 billion.

Return on average capital employed was 23 percent, averaging 37 percent over the last five years.

Earnings per oil-equivalent barrel were $14.85.

Total net production of liquids and natural gas available for sale was 4.4 million oil-equivalent barrels per day.

Proved oil and gas reserves additions were 3.5 billion oil-equivalent barrels, replacing 211 percent of production excluding asset sales.

Resource base additions totaled 14.6 billion oil-equivalent barrels; ExxonMobil’s total resource base now stands at 84 billion oil-equivalent barrels.

Exploration resource addition cost was $0.87 per oil-equivalent barrel.

Upstream capital and exploration spending was $27.3 billion, driven by an active exploration program, selective investment in a strong portfolio of development projects, and continued investment to enhance the value of existing assets.

4.4

million

oil-equivalent barrels
of net production
per day,
13 percent higher
than 2009

ExxonMobil’s focus on disciplined cost management and selective investments ensures that we continue to deliver strong results, while also continuing to grow our portfolio and progress technologies for the future.



(1) Royal Dutch Shell, BP, and Chevron values are estimated on a consistent basis with ExxonMobil, based on public information.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Identify and Selectively Capture the
Highest-Quality Exploration Opportunities

ExxonMobil’s fundamental exploration strategy is to identify, evaluate, selectively pursue, and capture the highest-quality resource opportunities ahead of competition. Our global organization allows us to explore diverse resource types across the opportunity life cycle, in all environments.

The combination of world-class technical expertise and an extensive global exploration database provides a distinct competitive advantage in the pursuit and capture of new opportunities. These opportunities include:

•		New exploration plays and basins that typically have high uncertainty but large resource potential to provide significant long-term resource growth;

•		Unconventional resources such as shale gas, tight gas, tight oil, coal bed methane, heavy oil, and oil sands that can provide profitable, long-plateau production volumes;

•		Further exploration of established hydrocarbon provinces and mature plays that provide near-term resource additions and production; and,

•		Discovered fields that are undeveloped or partially developed.

ExxonMobil screens all opportunities on a rigorous, consistent basis for technical quality, materiality, and commercial viability. We use our unique

geoscience capabilities and understanding of the global hydrocarbon endowment to identify, evaluate, and prioritize all quality resources within our global seriatim of the world’s highest-potential basins. Only the most robust opportunities are selected for further investment. Our approach to exploration has resulted in the successful capture of numerous new, high-potential resource opportunities year after year in any business climate. These captures provide broad exposure to multiple, high-potential plays in underexplored basins in areas that are close to major energy demand markets.

At year-end 2010, ExxonMobil’s net exploration acreage totaled 62 million acres in 33 countries, including more than 10 million acres of unconventional gas and oil resources. This strong acreage position provides a high-quality, geographically and geologically diverse portfolio of opportunities to deliver future resource additions and production growth.


Resource Additions/Acquisitions by Geographic Region		Resource Additions/Acquisitions by Resource Type

(percent, oil-equivalent barrels added, 2006-2010)		(percent, oil-equivalent barrels added, 2006-2010)

Our recent exploration activities and pursuits have added resources across all regions and resource types,
supporting future production growth.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

UpClose: XTO Energy Inc.

A 2010 highlight was ExxonMobil’s merger with XTO Energy Inc., a recognized industry leader in the development of unconventional resources. Following the June 2010 merger, ExxonMobil added roughly 60 trillion cubic feet gas-equivalent to our resource base, more than 2.9 billion cubic feet of equivalent daily gas production, and approximately 5 million net acres of leasehold. In addition to becoming the top domestic producer of natural gas in the United States, ExxonMobil acquired leading positions in a number of U.S. locations, including the Haynesville/Bossier, Barnett, Fayetteville, Woodford, and Marcellus shale gas plays; the Bakken shale oil play and multiple Permian Basin fields; the San Juan Basin and other Rocky Mountain coal bed methane plays; and, in the Freestone Trend and other tight gas reservoirs. The merger has established a premier unconventional resource organization with headquarters in Fort Worth, Texas.

2010 Opportunity Captures

In 2010, ExxonMobil continued to build on our already established strong position in all resource types with the capture of new opportunities in nine countries. These opportunities were captured at a competitive cost and span the full range of play maturities.

Argentina • ExxonMobil acquired 130,000 net acres in the Neuquen Province through license rounds and joint ventures in 2010.

Canada • ExxonMobil Canada and Imperial Oil acquired approximately 36,000 net acres in the Horn River Basin, British Columbia. Additional opportunities were added in the Cordova Basin and Beaufort Sea.

Iraq • In 2010, we finalized our agreement with the Iraq Ministry of Oil to redevelop and expand
the West Qurna (Phase I)
oil field in southern Iraq
(ExxonMobil interest, 60 percent).

Tanzania • ExxonMobil acquired a 35-percent working interest in deepwater Block 2. The exploration license covers 2.7 million acres in water depths ranging from 3200 to 11,200 feet.

Turkey • ExxonMobil signed an agreement to farm-in to a 25-percent interest in three sub-blocks of License 3922. This agreement covers approximately 7.4 million acres.

U.S. Onshore • Three high-quality resource opportunities augmented our onshore unconventional position in 2010. Two were in the Haynesville/Bossier play of East Texas and Louisiana with the acquisition of Ellora Energy Inc., and the execution of a separate joint venture. The third was a purchase of Fayetteville shale properties in Arkansas. All are contiguous with currently held properties. These opportunities increased ExxonMobil’s Haynesville/Bossier holdings by 67,000 net acres, and the Fayetteville acquisition added 157,000 net acres to our leasehold.

Other Captures • Australia Northwest Shelf, Poland Podlasie, and the U.K. North Sea.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Resources and Proved Reserves

Resources In 2010, ExxonMobil added 14.6 billion oil-equivalent barrels to our resource base. After accounting for production, asset sales, and revisions to existing fields, the resource base increased by 9.7 billion oil-equivalent barrels in 2010, bringing our resource base total to 84 billion oil-equivalent barrels. Proved reserves comprise 29 percent of our resource base.

ExxonMobil’s resource base is a major source of competitive advantage and is the largest resource base among the international oil companies. The size and diversity also support risk management and investment flexibility. The success of ExxonMobil’s global strategy for opportunity identification, evaluation, pursuit, and capture is demonstrated by the addition of an average of 5.2 billion oil-equivalent barrels of resource per year over the past five years.

We continue to grow our resource base through by-the-bit drilling success, discovered undeveloped resource capture, strategic acquisitions, and increased recovery from our existing fields. At year-end 2010, the XTO fields accounted for approximately 10 billion oil-equivalent barrels of the resource base, spanning the spectrum of shale gas, tight gas, shale oil, coal bed methane, and conventional reservoirs. Additional resources were added in Iraq, Athabasca and Horn River in Canada, onshore United States, and also deepwater exploration drilling in the Gulf of Mexico. Our exploration by-the-bit drilling program added 2.8 billion oil-equivalent barrels from additions spanning the globe and multiple resource types. Our exploration drilling by-the-bit resource base additions have averaged approximately 2.0 billion oil-equivalent barrels per year across the past decade.

Resource Base by Geographic Region

(percent, oil-equivalent barrels)

Resource Base by Type

(percent, oil-equivalent barrels)

ExxonMobil’s industry-leading resource base of 84 billion oil-equivalent barrels is diverse in terms of geology, resource type, and geography.

Resource Base Changes⁽¹⁾


				5-Year
(billions of oil-equivalent barrels)	2010			Average

Resource additions/acquisitions		14.6			5.2
Revisions to existing fields		(3.1	)		(0.6	)
Production		(1.7	)		(1.6	)
Sales		(0.1	)		(0.7	)⁽²⁾

Net change versus year-end 2009		9.7			2.3

We continue to achieve strong resource growth from consistent by-the-bit success, undeveloped resource capture, strategic acquisitions, and additional field recovery.

Exploration Resource Addition Cost⁽¹⁾

(dollars per oil-equivalent barrel)


(1)		See Frequently Used Terms on pages 98 through 101.

(2)		Includes impact of the Venezuela expropriation in 2007.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

The resource base is updated annually for new discoveries and to reflect changes in estimates of existing resources. Changes to existing resources may result from new drilling or from revisions to forecast recovery estimates achieved through the use of new technology. Updates may also occur due to fiscal regime changes, revisions in equity for existing assets, modifications to depletion plans, and from ongoing geoscience and engineering evaluations. Volumes produced or sold during the year are removed from the resource base at year end.

The largest single component of ExxonMobil’s resource base remains conventional oil and gas, which comprise 24 percent. Heavy oil, predominantly in Canada, accounts for just over 21 percent of the resource base. Over the last decade, our growing positions in both liquefied natural gas, and unconventional gas and oil have increased their combined share of the resource base to about 30 percent. The remainder is made up of arctic, deepwater, and acid/sour gas.

Effective use of ExxonMobil’s proprietary processes and best practices has resulted in continued low exploration resource addition cost. In 2010, our exploration resource addition cost was $0.87 per oil-equivalent barrel, and the five-year average cost was $1.00 per oil-equivalent barrel. The 2010 resource additions provide an attractive range of development opportunities for the future.

Proved Reserves At year-end 2010, our resource base included 24.8 billion oil-equivalent barrels of proved oil and gas reserves, equating to 15 years of reserves life at current production rates. With these resources and reserves, ExxonMobil maintains a diverse, global portfolio.

In 2010, ExxonMobil replaced 209 percent of reserves produced, including the effect of asset sales, by adding 3.5 billion oil-equivalent barrels to proved reserves while producing 1.7 billion oil-equivalent barrels. Excluding asset sales, our proved reserves replacement was 211 percent. These reserves represent a diverse global portfolio distributed evenly across geographic regions and resource types. Key reserves additions came from North American unconventional resources and from our operations in Russia, Nigeria, Norway, and Abu Dhabi. Our 2010 acquisition of XTO added significant proved reserves, primarily from unconventional onshore operations in the Barnett Shale, Freestone Trend, Arkoma Basin, and East Texas.

ExxonMobil’s reserves represent a diverse global portfolio distributed across many geographic regions and resource types.

ExxonMobil has added 10.2 billion oil-equivalent barrels to proved reserves over the last five years, more than replacing production. In that time frame, the development of new fields and extensions of existing fields have added an average of 0.8 billion oil-equivalent barrels per year to proved reserves. Revisions have averaged about 0.7 billion oil-equivalent barrels per year over the last five years, driven by effective reservoir management and the application of new technology. ExxonMobil has more than replaced reserves for 17 consecutive years.

The annual reporting of proved reserves is a product of ExxonMobil’s rigorous and structured management review process that is stewarded by a team of experienced reserves experts with global responsibilities. ExxonMobil calculates reserves consistent with SEC guidelines.

Proved Reserves Distribution⁽¹⁾

(billions of oil-equivalent barrels, year-end 2010)

We have a diverse global reserves portfolio, and our reserves are approximately evenly distributed between oil and gas.

Proved Reserves Replacement⁽¹⁾⁽²⁾

(percent of annual production replaced with proved reserves additions)


(1)		See Frequently Used Terms on pages 98 through 101.

(2)		Includes asset sales and the 2007 Venezuela expropriation.

ExxonMobil consistently replaces more reserves than we produce.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Maximize Profitability of Existing Oil and Gas Production

ExxonMobil applies the most cost-effective technology and operations management systems to all assets to ensure operations integrity, manage risk, and maximize the commercial recovery of hydrocarbons. This delivers strong profitability and life-cycle cost performance.

ExxonMobil possesses a diverse portfolio and leverages its global opportunity prioritization process and best practices to maximize the profitability of our existing oil and gas assets. As we integrate XTO into ExxonMobil, we will leverage best practices from each organization to drive further improvements.

Managing the Base Significant focus is placed on effectively managing base performance through rigorous operational surveillance and optimization. We continue to develop and selectively progress an inventory of the highest-quality investment opportunities to maximize the value of our existing assets. Through effective reservoir management and depletion planning, we continuously invest to increase economic resource recovery, maximize profitability, and ensure optimum long-term field performance. We continue to deliver new production volumes through drill wells, working over existing wells, and effective implementation of secondary and tertiary recovery programs. These include using injection of water, gas, or carbon dioxide, heavy oil steam flooding, and sour gas injection techniques to increase reservoir recovery. We continue to achieve efficiencies and cost savings in our drilling operations, including the application of our proprietary Fast Drill process, and our extended-reach drilling capabilities.

Focus on Operations Integrity Ensuring operations integrity is essential to our success. ExxonMobil’s Operations Integrity Management System (OIMS) encompasses all aspects of our operations and ensures risks are understood and appropriately mitigated.


(1)		Reflects data through December 31, 2010.

(2) Royal Dutch Shell, BP and Chevron values calculated on a consistent basis with ExxonMobil, based on public information.

UpClose: Sustainability

ExxonMobil Upstream is committed to responsibly delivering the energy required to meet growing global demand in a sustainable manner. We continuously work to reduce greenhouse gas emissions from our facilities.

Over the last five years, we have reduced our flare volumes by approximately 60 percent. This was achieved by pursuing operational best practices to increase reliability and the implementation of gas utilization projects. We are applying our Global Energy Management System across the Upstream, and have a strong focus on continually improving our results. In addition, through projects such as our Controlled Freeze Zone demonstration plant, we are pursuing technology breakthroughs for the future.

Another area of focus is reducing water use across our facilities. In our Cold Lake oil sands development, we have reduced freshwater use by 90 percent, and now recycle about 95 percent of the water in the facility.

Our commitment to operational excellence underpins our success, and delivers continued safety, security, health, and environmental performance improvement.

OIMS is used worldwide and compliance is tested on a regular basis to ensure consistency of approach.

ExxonMobil achieves high facility uptime by leveraging a suite of equipment maintenance best practices developed over our considerable operational history. Large-scale maintenance activities are rigorously planned and executed using a globally consistent shutdown management process to minimize production impact. Over the last five years, our facility reliability, measured as uptime, has been on average 3 percent higher for our ExxonMobil operations than for similar facilities in our portfolio that are operated by others.

Earnings We remain highly competitive among our peers on profitability due to our commitment to investment discipline and selectivity, application of innovative technology, superior execution capabilities, and the ability to maximize economic resource recovery.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Production Volumes ExxonMobil’s 2010 net oil-equivalent production of 4.4 million barrels per day was an increase of 13 percent over 2009 levels. Net liquids production was 2.4 million barrels per day, and net natural gas available for sale totaled 12.1 billion cubic feet per day. Excluding impacts associated with entitlement volume effects, quota and divestments, net oil-equivalent production increased by 14 percent from 2009, primarily driven by the XTO merger, project activity in Qatar, and ongoing drilling programs in Africa and North America.

Looking forward, new projects and work programs are forecast to offset existing field declines. Near-term activity will be focused on large liquids projects in Iraq and Canada, liquefied natural gas projects in Papua New Guinea and Australia, and unconventional gas activity in the United States. Longer-term growth will be generated by leveraging ExxonMobil’s technical expertise in execution of a diverse global project portfolio. Many of these projects are already being pursued and have extended plateau production profiles that run for decades.

The forward-looking projections of production volumes in this document are reflective of our best assumptions regarding technical, commercial, and regulatory aspects of existing operations and new projects. Factors that could have an impact on actual volumes include project start-up timing, regulatory changes, quotas, changes in market conditions, asset sales, operational outages, severe weather, and entitlement volume effects under certain production sharing contracts and royalty agreements.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Invest in Projects that Deliver Superior Returns

ExxonMobil continues to deliver superior returns from Upstream projects through disciplined investments, comprehensive planning, proprietary technology, and industry-leading project execution.

Production Execution Performance


(Percent, 2006–2010 Average)	Cost		Schedule

ExxonMobil Operated		101		109
Operated by Others		114		119

As project scale and complexity increase across industry, bringing new energy supplies to market, on budget and on schedule, becomes more challenging. ExxonMobil’s comprehensive suite of business processes, project execution tools, and project management expertise ensures maximum value to resource owners and to our shareholders.

Superior project execution begins with selecting the design and operating concept that will be robust through a range of uncertainties and will deliver maximum value over the life of the asset. It requires a commitment to, and investment in, technology to develop innovative solutions that continue to improve safety, minimize environmental impact, reduce cost, increase reliability, and deliver profitable volumes growth. ExxonMobil devotes a great deal of time to front-end execution planning to thoroughly identify and understand cost and schedule risks during costly project phases, resulting in industry-leading project performance.

We continue to improve project execution results driven by our functional organizations’ commitment to facilitating the sharing of project learnings and best practices swiftly across all global divisions. Successful application of best practices and a strong opportunity base continue to drive superior project returns.

ExxonMobil has a large, geographically diverse portfolio of more than 130 major projects that are expected to develop more than 26 billion oil-equivalent barrels (net). Many of these developments

Projects by Geographic Region

(percent, number of projects)

ExxonMobil’s extensive portfolio of over 130 major projects allows selective investment decisions.

Resources in Projects by Project Type

(percent, oil-equivalent barrels)

Our diverse project portfolio is expected to develop over 26 billion oil-equivalent barrels (net) across all regions and resource types.

are located in remote and challenging environments, and include deepwater, heavy oil/oil sands, conventional oil and gas, unconventional gas, arctic, liquefied natural gas (LNG), and acid/sour gas projects.

The diversity and scale of this portfolio provides ExxonMobil the ability to selectively invest in projects that deliver robust financial performance and maximize profitable volumes growth over a wide range of economic conditions.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Capitalize on Growing Natural Gas and Power Markets

ExxonMobil employs a worldwide team of commercial experts, with detailed knowledge of global energy markets, to maximize the value of the company’s gas, natural gas liquids, and power interests.

Reliable economic supplies of natural gas and power are fundamental to fuel the world’s economic development. Over the coming decades, natural gas is expected to play an increasingly important role in meeting the world’s energy needs. ExxonMobil sold 14.7 billion cubic feet per day of natural gas in 2010, and was active across the gas value chain in most major markets. Our global presence, combined with an ability to leverage expertise across our Upstream, Downstream, and Chemical businesses, enables us to deliver innovative integrated solutions. This provides a sustainable competitive advantage and positions ExxonMobil to help meet the world’s growing natural gas and power demands.

In North America, ExxonMobil is a major gas producer and processor with production from the Gulf of Mexico, onshore Gulf Coast, Mid-Continent and Northeast United States, western Canada, and offshore eastern Canada. Following the XTO merger, we are now the leading producer of natural gas and have the largest proved gas reserves in the United States. We continue to pursue development of natural gas resources in Alaska and are working with TransCanada and others to advance a pipeline from the Alaskan North Slope to North American markets.

In Europe, ExxonMobil is a leading natural gas producer through ownership in key assets in the Netherlands, Germany, and both the U.K. and Norwegian sectors of the North Sea. In Asia Pacific, ExxonMobil remains among the largest suppliers of natural gas in Australia and Malaysia, and also sells gas in Thailand and far east Russia. In the Middle East, the recent start-up of Phase 2 of the Al Khaleej Gas project resulted in a major increase in pipeline gas sales in Qatar and associated natural gas liquids sales.

ExxonMobil has a significant global position in liquefied natural gas (LNG). We are involved in successful ventures in Qatar and Indonesia, which provide substantial volumes of LNG to key European and Asian markets, and the Americas. ExxonMobil’s LNG supplies from Qatar, which has the largest trains in service anywhere in the world, increased significantly with the recent completion of four new 7.8-million-tonne-per-year trains. ExxonMobil has ownership interest in LNG regasification facilities in the United Kingdom and offshore Italy, as well as the Golden Pass terminal in Texas that began commissioning and achieved first gas send-out in 2010. These terminals and our suite of sales arrangements position us well to access multiple markets and maximize LNG value. New LNG projects in which ExxonMobil has an interest are also under construction in Papua New Guinea and Western Australia.

ExxonMobil also continues to pursue unconventional gas opportunities around the world. In North America, the merger with XTO Energy Inc. significantly expanded our presence in some of the most prolific unconventional basins. In Europe, we continue to assess multiple shale gas and coal bed methane (CBM) opportunities, including those in Germany and Poland. In Indonesia, we are evaluating CBM opportunities and potential options for gas commercialization.

In addition to our extensive natural gas interests, we also manage about 1 million barrels per day of natural gas liquids, generate a significant amount of power, and are a leading producer of helium, through our Shute Creek facility in Wyoming and our interests in Qatar.

Power Activities ExxonMobil has interests in about 16 gigawatts of power generation capacity worldwide. This includes a majority interest in the Castle Peak Power Company that generates electricity for consumers in Hong Kong and mainland China. In Nigeria, ExxonMobil and our partners continue with front-end engineering and design of a new 500-megawatt power plant. ExxonMobil is an industry leader in the application of cogeneration technology with interests in almost 5 gigawatts of capacity across 100 installations. We continue to look for cogeneration opportunities around the world to efficiently supply the power and steam demands of our facilities.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Major Development Projects

ExxonMobil participated in three major project start-ups in 2010. Beyond 2010, an additional 56 major projects are in various stages of planning, design, and execution, from an industry-leading portfolio containing over 130 projects.

RasGas Train 7 • RasGas Train 7 (ExxonMobil interest, 30 percent) started up in 2010. Train 7 is a 7.8-million-tonne-per-year liquefied natural gas (LNG) train owned by Ras Laffan Liquefied Natural Gas Company (3), a joint venture between Qatar Petroleum and ExxonMobil (ExxonMobil interest, 30 percent). Train 7 is the fourth in a series of mega LNG trains recently started up in Qatar. These first-of-a-kind megatrains incorporate the latest technologies in the industry and are the result of close collaboration between ExxonMobil and our partner

In 2010, ExxonMobil in partnership with Qatar Petroleum, completed our world-class integrated projects that will deliver gas from the Qatar North Field to markets across the world, supporting Qatar’s position as the largest LNG producer in the world.

Qatar Petroleum. Train 7 markets include Asia and other markets worldwide.

Golden Pass LNG Terminal • Golden Pass LNG regasification terminal (ExxonMobil interest, 18 percent) in Sabine Pass, Texas, received its first LNG cargo from Qatar, began commissioning, and achieved first gas send-out in 2010. The terminal contains two ship unloading berths, five LNG storage tanks, and regasification equipment that converts LNG back into gas for delivery via the Golden Pass pipeline, interconnecting with multiple interstate and intrastate lines. The terminal will have the capacity to supply up to 2 billion cubic feet of gas per day to the U.S. market.

Sakhalin-1 Odoptu • Sakhalin-1 Odoptu (ExxonMobil interest, 30 percent) started up in 2010 with initial production of over 50 thousand barrels of oil per day. Development of Odoptu included a new world record for well reach and total length using extended-reach drilling to access reserves over 7 miles from shore. Production from Odoptu flows via a 49-mile, 16-inch pipeline to the existing onshore production facility at Chayvo.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

MAJOR PROJECT START-UPS

Target Peak

Production (Gross)

ExxonMobil

Liquids

Gas

Working

(KBD)

(MCFD)

Interest (%)

2010 (Actual)

Qatar

RasGas Train 7

1250

Russia

Sakhalin-1 Odoptu

–

U.S.

Golden Pass LNG Terminal

–

2011-2013 (Projected)

Angola

Kizomba Satellites Phase 1

100

–

Pazflor

200

–

Plutao-Saturno-Venus-Marte

150

–

Australia

Kipper/Tuna

175

Turrum

200

Canada

Kearl Initial Development

170

–

100

Kazakhstan

Kashagan Phase 1

360

–

Malaysia

Telok

–

350

Nigeria

Usan

180

–

Etim/Asasa Pressure

–

Maintenance

Satellite Field Development Phase 1

–

2014+ (Projected)

Angola

AB31 Southeast Hub

220

–

AB32 Kaombo Split Hub

210

–

Cravo-Lirio-Orquidea-Violeta

160

–

Kizomba Satellites Phase 2

–

Australia

Gorgon Jansz

2545

Gorgon Area Expansion

850

Gippsland Satellites

–

Scarborough

–

1190

Canada

Cold Lake Nabiye Expansion

–

100

Cold Lake LASER Expansion

–

100

Firebag

280

–

Hebron

130

–

Hibernia Southern Extension

–

Kearl Expansion

170

–

100

Mackenzie Gas Project

830

Syncrude Aurora South Phases 1 and 2

200

–


		Target Peak
		Production (Gross)				ExxonMobil
		Liquids		Gas		Working
		(KBD)		(MCFD)		Interest (%)


2014+ (Projected, continued)
Indonesia	Banyu Urip		165		15		45	n
	Natuna		–		1100		**	n
Iraq	West Qurna (Phase I)*		2825		–		60	5
Italy	Tempa Rossa		50		15		25	l
Kazakhstan	Aktote		50		850		17	l
	Kashagan Future Phases		1190		–		17	l
	Tengiz Expansion		250		–		25	l
Malaysia	Damar Gas		5		260		50	n
Nigeria	Bonga North		100		60		20	l
	Bonga Southwest		200		15		16	l
	Bosi		135		–		56	n
	Erha North Phase 2		50		–		56	n
	QGFE DomGas		15		300		40	n
	Satellite Field Development Phase 2		80		–		40	n
	Uge		110		20		20	n
	Usan Future Phases		50		–		30	l
	Usari Pressure Maintenance		50		–		40	n
Norway	Dagny		65		185		33	l
	Luva		–		600		15	l
Papua New Guinea	PNG LNG		40		940		33	n
Qatar	Barzan		55		1400		7	5
Russia	Sakhalin-1 Arkutun-Dagi		90		–		30	n
	Sakhalin-1 Future Phases		30		800		30	n
United Arab Emirates	Upper Zakum 750		750		–		28	5
U.K.	Fram		20		140		72	l
U.S.	Alaska Gas/Point Thomson		70		4500		36	**
	Hadrian		100		375		50	n
	Julia		30		–		50	n
	LaBarge Field Expansion		–		200		100	n

n ExxonMobil Operated 5 Joint Operation l Co-Venturer Operated

* Field debottlenecking in 2011 ** Pending Final Agreements

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Maximize Resource Value through High-Impact Technologies

Our commitment to technology provides a competitive advantage in exploration, project development, oil and gas recovery, and production operations. Using our integrated technologies, we have achieved advances in deepwater, arctic, heavy oil, and most recently, liquefied natural gas development, enabling us to unlock resource potential previously considered uneconomic. This same multidisciplinary approach will allow us to achieve advances in the development of unconventional gas both in North America and around the globe.

Advancing Integrated Technologies to Develop Shale Gas Resources ExxonMobil is developing integrated technologies for optimizing locations to drill and produce shale gas safely and economically. This research ranges from the effectiveness of hydraulic fractures in well stimulation to the prediction of shale gas properties from stratigraphic models. Our research is being assisted by the integration of knowledge and extensive data from our recently expanded unconventional portfolio.

Proprietary technologies in basin analysis and stratigraphy lay the foundation for predicting the occurrence of shale gas plays in sedimentary basins. ExxonMobil has new technology for reconstructing the movement of tectonic plates in

Integrated technologies provide ExxonMobil with advantaged business solutions.

three dimensions. Our reconstructions are now more realistic because they incorporate deformation of the crust within the plates. This approach provides better predictions of subsidence, uplift, and heat flow, which are key controls on the types of sediments deposited in a basin. These new capabilities enhance our understanding of regional geology and are especially useful in exploring new basins for all types of resources.

Our geologists apply ExxonMobil’s expertise in the stratigraphy of fine-grained rocks to predict the occurrence, distribution, and properties of organic-rich shales in the context of regional geology. Our stratigraphic tools support early recognition of shale gas plays and the prediction of optimal drilling locations. They help explain the variations in shale gas reservoir properties that can impact well performance and thus contribute to optimizing development strategies. Our emerging technology in fracture prediction from seismic data and new laboratory capabilities for measuring ultra-low permeabilities also play a key role in our understanding of these resources.

Prediction of Natural Fractures from Seismic Data • ExxonMobil is using seismic technology in innovative ways to predict the distribution of natural fractures, which are important pathways for hydrocarbon flow in tight reservoirs. This technology uses selected seismic responses to

predict the intensity and orientation of fractures. These predictions help identify areas of enhanced flow and contribute to optimizing well placement and well paths. This emerging seismic technology is being applied to carbonate reservoirs in the Middle East and is contributing to the definition of fractured, shale gas plays in North America. In addition, ExxonMobil is using an advanced, specially designed seismic survey to characterize fracture networks in tight gas sandstones in Colorado.

Relative Permeability Testing • ExxonMobil is extending our distinguishing capabilities in laboratory flow studies to ultra-low permeability rocks, such as shales that serve as tight gas reservoirs. We use state-of-the-art equipment, pioneering analytical techniques, and best practices based on decades of experience to study complex flow through rock samples in the laboratory. We simulate actual reservoir conditions and measure the relative amounts of oil, gas, and water that flow through samples during the tests. The results are critical to quantifying hydrocarbon flow during a field’s life and have helped define, develop, and deplete reservoirs in over 40 countries. ExxonMobil is developing new laboratory methods and tools for flow studies of shale gas reservoirs to use in developing our expanded unconventional portfolio.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Rock Properties from Logs in
High-Angle and Horizontal Wells

ExxonMobil has developed leading-edge technology for evaluating rock and fluid properties in high-angle and horizontal (HA/HZ) wells. Logging tools have traditionally been calibrated to vertical wells, so tool responses need to be corrected for deviated and horizontal well paths. We have developed proprietary software that corrects well log responses for wellbore geometry and the physics of logging tools, resulting in better quantitative interpretations of rock and fluid properties for use in all business stages. The state-of-the-art workflow and patented techniques calculate accurate in-place hydrocarbon reserves using log data from HA/HZ wells, which can provide business advantages in a variety of settings.

Improving Reservoir Recovery

Stimulating Flow in Carbonates • In many of ExxonMobil’s carbonate assets, acid injection treatments are used to increase the connectivity of the well to the reservoir by creating long, highly conductive conduits called “wormholes.” We are applying a suite of leading-edge technologies to gain key insights into the growth of wormholes and their effects on long-term well performance. Laboratory experiments, which used rock samples approximately 2000 times the volume of those used previously, produced wormhole networks on a scale that permitted more thorough investigation of their growth in three dimensions. Detailed images of the wormholes were obtained by contracting with the U.S. Air Force for access to one of the most powerful X-ray scanners in the world. These 3D images have been integrated with ExxonMobil’s expertise in computational modeling to understand how the wormholes promote flow into a well. Establishing an effective, flow-efficient connection to the reservoir is a key element in maximizing and sustaining production.

New Technology for Enhanced Bitumen Recovery • We continue to pursue additional technologies for enhancing bitumen recovery. These new processes focus on reducing environmental impact and improving long-term access to heavy oil resources. Unlike many other heavy oil technologies, ExxonMobil’s Cyclic Solvent Process (CSP) is a nonthermal recovery process. A cycle consists of injecting a solvent through a horizontal wellbore to reduce the viscosity of heavy oil in place, followed by production of a solvent-oil mixture through the same wellbore; this process is then repeated. The primary solvents considered for this process consist of naturally occurring light hydrocarbon solvents, such as propane. CSP has the potential to substantially reduce greenhouse gas emissions over existing thermal recovery techniques, while greatly reducing energy and water use. It may also provide access to additional resources, such as reservoirs with thin pay zones or low bitumen saturations, which are challenging to produce with current thermal recovery processes.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Continuing to Extend Drilling Boundaries

Borehole Management • ExxonMobil has developed a borehole management process that integrates innovative technologies and operating practices to continue drilling longer, more deviated wells in greater contact with the reservoir. One of the challenges in drilling extended-reach wells is managing the behavior of cuttings in the borehole. The accumulation of cuttings can interfere with moving the drillstring and inserting casing. ExxonMobil is using leading-edge laboratory capabilities and advanced computational techniques

to simulate the downhole process of pulling and pushing pipe through accumulations of cuttings. This research helps optimize the amount of cuttings in wells to keep boreholes stable, smooth, and serviceable during the drilling process. Faster, more efficient removal of cuttings increases the rate of penetration realized by ExxonMobil’s Fast Drill process and Vybs technology for managing downhole vibrations.

Pursuing Further Advances in Operational Excellence

Advanced 3D Safety Training • ExxonMobil has realized continuing improvements in plant reliability, resulting in higher uptime and fewer facility upsets that require response from operations staff. We are developing an advanced, 3D immersive visualization environment for safety training to ensure that staff members remain prepared to respond to facility upsets appropriately. This training environment will provide opportunities to learn and practice quick, effective safety responses through realistic simulations. Current technology provides a 3D view of a facility with interactive capabilities. ExxonMobil is adding functionalities to make the simulated environment more
realistic and the safety training more effective.

Monitoring the Health of Marine Environments • ExxonMobil is expanding our suite of technologies for long-term monitoring of sensitive marine ecosystems. A study led by ExxonMobil Research

Our technologies will enable us to expand energy supply in a safe and environmentally responsible way.

Qatar evaluated the effectiveness of chlorophyll fluorometry in monitoring the health of sea grass colonies and coral reefs. This noninvasive technique measures fluorescence to determine the health of sea grasses and symbiotic algae, which affect the health of the host corals. The study conducted detailed visual assessments of ecosystems along with measurements of seawater temperature, underwater light intensity, and water quality. Through this work, we have demonstrated that chlorophyll fluorometry can improve our ability to monitor the health of these sensitive ecosystems.

External Collaboration for Selected Technologies • ExxonMobil continues to realize value through external research collaborations with universities, national laboratories, and other industries to provide leading-edge technology. We use this approach to pursue well-aligned, novel opportunities that can accelerate our research. These collaborative efforts can incorporate a broad range of disciplines and engage various types of organizations around the world. For example, ExxonMobil developed and directs an alliance with universities in Europe and the United States to research the fundamental controls on flow in carbonates. This multidisciplinary network has stimulated innovation and delivered proprietary advances for use in next-generation methods for geologic modeling and flow simulation. ExxonMobil is also benefiting from technical collaboration between the oil-and-gas and medical communities in Houston, Texas. This creative, interdisciplinary initiative has produced a flow simulation and visualization capability useful in flow assurance studies, ranging from the effectiveness of artificial heart valves to progressing leading-edge sand-screen technology for wellbores.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Worldwide Upstream Operations

ExxonMobil has interests in exploration and production acreage in 38 countries and production operations in 24 countries.

THE AMERICAS

ExxonMobil’s portfolio ranges from mature onshore fields to future developments in the ultra-deepwater offshore, and includes significant positions in unconventional gas and heavy oil plays. Operations in the Americas contributed 27 percent of net oil and gas production and 24 percent of Upstream earnings in 2010.

United States

ExxonMobil is a leading reserves holder and producer of oil and gas in the United States. Following the merger with XTO Energy Inc. in 2010, ExxonMobil became the largest producer of natural gas in the United States. We maintain a significant position in all major producing regions, including the Gulf of Mexico and Gulf Coast, the Mid-Continent, California, and Alaska. Technological improvements, operational efficiency, and high-quality drilling programs are extending the lives of our base producing fields, some of which have been onstream for decades. Our portfolio is being


Americas Highlights	2010		2009		2008

Earnings (billions of dollars)		5.9		3.8		9.8
Proved Reserves (BOEB)		9.8		7.1		6.9
Acreage (gross acres, million)		51.4		49.5		56.4
Net Liquids Production (MBD)		0.7		0.7		0.7
Net Gas Available for Sale (BCFD)		3.2		1.9		1.9

Americas Production

(millions of oil-equivalent barrels per day, net)

The Americas contributed
27%

of production this year

augmented by activity in multiple unconventional gas and oil plays and through future new developments arising from our deepwater Gulf of Mexico acreage position.

Gulf of Mexico/Gulf Coast

ExxonMobil is a major oil and gas producer in the offshore Gulf of Mexico with average net production of 87 thousand barrels of liquids per day and 388 million cubic feet of gas per day in 2010. Onshore net production in Texas and Louisiana added 72 thousand barrels of liquids per day and 1282 million cubic feet of gas per day.

Deepwater • In the deepwater of the Gulf of Mexico, drilling operations on our Hoover platform (ExxonMobil interest, 67 percent) were delayed in 2010 as a result of the Outer Continental Shelf Drilling Moratorium, and we are awaiting approval to restart. The Hoover platform is located in more than 4800 feet of water, and produces oil and gas from the Hoover field and several subsea tiebacks.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

ExxonMobil has a significant exploration portfolio of 1.4 million net acres in the deepwater Gulf of Mexico. Development planning and further block evaluation activity continues at the Hadrian discovery (ExxonMobil interest, 50 percent) in Keathley Canyon. Our planned 2010 exploration drilling was delayed by the drilling moratorium and is scheduled to commence in 2011. Additionally, development planning activities are progressing on the Lower Tertiary Julia discovery in Walker Ridge.

Conventional • The Golden Pass liquefied natural gas (LNG) regasification terminal (ExxonMobil interest, 18 percent) in Sabine Pass, Texas, received its first LNG cargo from Qatar, began commissioning, and achieved first gas send-out in 2010. The terminal contains two LNG ship unloading berths, five full containment storage tanks, and regasification facilities that convert LNG back into gas for delivery via an export pipeline. The terminal will have the capacity to supply up to 2 billion cubic feet of gas per day to the U.S. grid. It is being supplied primarily by gas produced from Qatar’s North Field in the Arabian Gulf, the largest non-associated gas field in the world.

The Mobile Bay development offshore Alabama contributed net production of 169 million cubic feet of gas per day during 2010. Execution of a project to consolidate plants to improve the efficiency and environmental performance of the Mobile Bay onshore plants was also completed in 2010.

In Texas, the King Ranch gas plant celebrated 50 years of operation in 2010, processing an average of 434 million cubic feet of inlet gas per day.

UpClose: Marine Well Containment

ExxonMobil, on behalf of the Marine Well Containment Company, a not-for-profit industry organization, is leading the development of a rapid response system that will be available to capture and contain oil in the event of a potential future underwater blowout in the deepwater Gulf of Mexico. The containment system will be flexible, adaptable, and available to initiate deployment within 24 hours of notification for a wide range of well designs, oil flow rates, and weather conditions. Engineering and construction activities are in progress for this purpose-built system, which will be capable of capturing, storing and offloading up to 100 thousand barrels of oil per day in water depths up to 10,000 feet.

In the Permian Basin region of West Texas and New Mexico, we have significant operations, active drilling, and hold 470,000 net acres.

Unconventional • Our fastest growing unconventional play is in the Haynesville/Bossier Shale of East Texas and Louisiana, where we hold approximately 240,000 net acres. Gross-operated production reached 250 million cubic feet of gas per day by year end, more than four times year-end 2009, as a result of a very active drilling program. Haynesville development focused in the prolific southern core area, and we also commenced testing in the highly prospective overlying Bossier Shale reservoir. In 2010, we added to our position in this play with the acquisition of Ellora Energy Inc., and also the formation of a joint venture.

In the Barnett Shale field of North Texas, we hold 245,000 net acres primarily in the core of the play. In 2010, we drilled 200 wells in the Barnett field, increasing gross-operated production to 860 million cubic feet of gas per day. Through efficiency gains, we continue to control costs and maximize profitable growth; and over the past five years, the time between the start of drilling and rig release has been reduced by 50 percent.

In the Freestone tight gas trend in East Texas, we drilled 199 wells in 2010. We continue to develop our 290,000 net acres of leasehold with traditional multizone vertical completions coupled with a strong inventory of horizontal locations.

Delineation activities are also ongoing across ExxonMobil’s 120,000 net acres in the liquids-rich Eagle Ford shale play of South Texas, where we drilled 15 wells in 2010.

Mid-Continent and Appalachia

ExxonMobil has oil and gas production throughout the mid-continent states, including Wyoming, Utah, North Dakota, Montana, Colorado, Kansas, Oklahoma, Arkansas, and New Mexico, as well as Appalachian production from Pennsylvania and West Virginia. Average net production from these areas was 32 thousand barrels of liquids per day and 885 million cubic feet of gas per day in 2010.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Conventional • Across our portfolio, several enhanced oil recovery projects are being developed to extend the life of mature mid-continent assets, such as at our Means, Fullerton, Talco, and Hawkins fields.

The LaBarge development (ExxonMobil interest, 100 percent) in Wyoming comprises the Madison, Tip Top, and Hogsback fields, and the Shute Creek gas processing plant. The operation includes the longest sour gas pipeline in the United States and the world’s largest helium recovery and physical solvent gas sweetening plants. A project to provide additional compression to support increased carbon dioxide (CO₂) capture for enhanced oil recovery and reduced CO₂ emissions was completed in 2010. Additionally, implementation of a project to improve environmental performance of the Shute Creek plant’s compressor engines is progressing, with expected start-up in 2012. In 2010, the LaBarge facilities processed an average of 674 million cubic feet of inlet gas per day.

A demonstration plant at the Shute Creek facility that will test ExxonMobil’s proprietary Controlled Freeze Zone technology was commissioned in 2010, and is beginning the testing phase. By using a single-step cryogenic separation process, this technology could lower the cost of removing CO₂ and hydrogen sulfide from natural gas. It could also assist in the application of carbon capture and storage to reduce greenhouse gas emissions.

Unconventional • In the Fayetteville shale gas play of the Arkoma Basin, ExxonMobil’s position grew to approximately 550,000 net acres. In 2010, gross-operated production more than doubled following an active drilling program, and ended the year at more than 300 million cubic feet of gas per day. Multiple drilling pilots are under way to optimize well spacing and increase ultimate recovery.

In Oklahoma, we are currently developing our leasehold in the Woodford Shale, where we hold 205,000 net acres. Our Woodford production increased by approximately 30 percent in 2010.

ExxonMobil holds a strong U.S. unconventional acreage position with 4.8 million net acres in our portfolio.

ExxonMobil holds 410,000 net acres in the country’s premier unconventional oil play, the Bakken Shale of North Dakota and Montana. We drilled a total of 63 wells in the Bakken play in 2010.

In the Marcellus Shale, ExxonMobil is actively delineating our leasehold of 390,000 net acres. Drilling continues in north central, northeastern, and southwestern Pennsylvania and northern West Virginia. ExxonMobil will also evaluate additional potential in 2011 through drilling and early production from a joint venture operation.

In Colorado, the Piceance development (ExxonMobil interest, 100 percent) contributed net production of 189 million cubic feet of gas per day in 2010. ExxonMobil has approximately 300,000 acres under lease in the Piceance Basin. During 2010, significant progress was made to enhance drilling technology to reduce the overall footprint of future drilling well pads, thereby reducing development costs and environmental impacts.

The San Juan region includes operations in the San Juan Basin of Colorado and New Mexico, the Raton Basin in southeastern Colorado, and the Uinta Basin in eastern Utah. ExxonMobil’s leasehold encompasses 660,000 net acres across these areas, which are productive from both tight gas sands and coal bed

methane reservoirs, and also prospective for select gas shales. These mature fields have a steady production profile characteristic of long-lived production assets.

California

ExxonMobil net production from fields both onshore and offshore California averaged 101 thousand barrels of liquids per day and 35 million cubic feet of gas per day during 2010.

The Santa Ynez development (ExxonMobil interest, 100 percent) consists of three platforms located 5 miles offshore Santa Barbara and a processing plant in Las Flores Canyon. ExxonMobil continues to successfully employ world-class extended-reach drilling from these platforms to increase recovery. ExxonMobil also has a 48-percent equity share in the Aera onshore operations, comprising 10 fields and about 11,000 wells producing a mixture of heavy and conventional oil with associated gas.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Alaska

ExxonMobil is among the largest producers in Alaska with average net production of 117 thousand barrels of liquids per day in 2010.

Development activities continued at Point Thomson with the completion of two wells. The project continues to advance design and regulatory permitting to meet targeted first production in the 2014–2015 winter season.

ExxonMobil continues to be the largest holder of discovered gas resources on the North Slope of Alaska. Joint development of the Alaska Gas Pipeline project between ExxonMobil and TransCanada is progressing, which will enable treatment and transportation of natural gas from the Alaskan North Slope to North American gas markets. The first open season in the history of the North Slope concluded on July 30, 2010. Key commercial and regulatory activities are progressing.

Canada

ExxonMobil is one of the leading oil and gas producers in Canada through our wholly-owned affiliate ExxonMobil Canada and majority-owned affiliate Imperial Oil (ExxonMobil interest, 69.6 percent). Through these entities, ExxonMobil has one of the country’s largest resource positions and a significant portfolio of major new projects, both onshore and offshore.

Offshore Canada Operations

The Hibernia field (ExxonMobil interest, 33 percent) offshore Newfoundland is operated by Hibernia Management and Development Company Ltd., using ExxonMobil personnel and processes. In 2010, Hibernia’s production averaged 154 thousand barrels of oil per day.

In October 2010, the Canada-Newfoundland and Labrador Offshore Petroleum Board approved the Hibernia Southern Extension project (ExxonMobil interest, 27 percent) development plan amendment allowing the co-venturers to proceed with development. Front-end engineering and design work has been completed. The project will include a subsea tieback to the existing Hibernia platform, and will access recoverable resources of approximately 140 million oil-equivalent barrels.

In 2010, the co-venturer-operated Terra Nova development (ExxonMobil interest, 22 percent) produced 68 thousand barrels of oil per day. Located in 300 feet of water, Terra Nova consists of a unique, harsh-environment-equipped floating production, storage, and offloading vessel and 26 subsea wells that are expected to recover approximately 400 million oil-equivalent barrels.

The ExxonMobil-operated Sable Offshore Energy project (ExxonMobil interest, 51 percent; Imperial Oil interest, 9 percent) in Nova Scotia consists of five producing fields. Production in 2010 averaged 291 million cubic feet of gas per day and 14 thousand barrels of associated natural gas liquids per day.

The Hebron project (ExxonMobil interest, 34 percent) is an ExxonMobil-operated oil development located in 300 feet of water offshore Newfoundland. Engineering and contracting activities are progressing, leveraging extensive ExxonMobil global experience with gravity-based facilities and project execution in challenging arctic conditions. Construction of the gravity-based structure will be undertaken in eastern Canada. The development is being designed to recover over 600 million barrels of oil.

At year end, ExxonMobil had interests in more than 4 million acres in two deepwater exploration blocks in the Orphan Basin offshore eastern Canada (ExxonMobil Canada interest, 15 percent; Imperial Oil interest, 15 percent). The first exploration well was drilled in this arctic area in 2007 and a second was drilled in 2010.

In 2010, ExxonMobil and Imperial Oil entered into a Joint Operating Agreement in the Beaufort Sea, resulting in a 50-percent interest in EL 446 and an adjoining block, EL 449 (ExxonMobil Canada interest, 25 percent; Imperial Oil interest, 25 percent). The blocks are located approximately 75 miles offshore, and cumulatively cover approximately 1 million acres. Interpretation of 3D seismic data collected in 2008 and 2009 is ongoing and plans for the first exploration well in this operationally challenging arctic area are progressing.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Onshore Canada Operations

The Cold Lake field (Imperial Oil interest, 100 percent) and the Syncrude oil sands mining operation (Imperial Oil interest, 25 percent) account for the majority of our liquids production in western Canada. In 2010, Cold Lake averaged 144 thousand barrels of oil per day and Syncrude’s production of synthetic crude averaged 292 thousand barrels per day.

The Cold Lake field in Alberta is the largest thermal in situ heavy oil project in the world. It has over 4000 wells directionally drilled from multiple satellite pads tied back to central facilities, which helps to reduce surface land requirements. Cyclic steam stimulation is used to recover bitumen, which is too heavy and viscous for conventional production. Recovery is being increased through the use of leading-edge thermal recovery technologies. A commercial application of the proprietary LASER (Liquids Addition to Steam for Enhanced Recovery) technology was implemented in 2007 and a pilot of SA-SAGD (Solvent-Assisted, Steam-Assisted Gravity Drainage) technology started operation in late 2009.

Engineering work is under way and early construction work has commenced on the Nabiye project, the next expansion phase of Cold Lake (Imperial Oil interest, 100 percent). Steam injection will be utilized to develop an additional 35 thousand barrels of bitumen per day at peak rate.

The Kearl oil sands project (combined ExxonMobil and Imperial Oil interest, 100 percent) is developing a world-class resource in northern Alberta expected to exceed 4 billion barrels. Construction and fabrication activities are under way on the Kearl Initial Development project with mining and extraction facilities scheduled for completion in 2012. Initial production will start at approximately 110 thousand barrels of bitumen per day with future debottlenecking and expansion increasing production to 345 thousand barrels of bitumen per day with the full development. Front-end engineering work is progressing on the Kearl Expansion project.

In addition, Syncrude Canada Limited (Imperial Oil interest, 25 percent) is advancing concept selection activities on the Aurora South project to further develop the resource base in northern Alberta. The proposed open-pit, truck and shovel mining operation is planned in two phases, which combined, would produce 200 thousand barrels of bitumen per day.

ExxonMobil also continued evaluating its oil sands acreage in the Athabasca region in 2010. Core hole and seismic programs continued on both in situ and mining leases. These evaluation programs will continue in 2011.

In northeastern British Columbia, evaluation of our acreage in the Horn River Basin (ExxonMobil Canada, 50 percent; Imperial Oil, 50 percent) continued with a 12-well drilling

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

program during the 2009–2010 winter drilling season. ExxonMobil and Imperial Oil also expanded their land position to approximately 340,000 net acres in 2010, strengthening ExxonMobil’s position as the largest net landholder in the basin. Plans are progressing to drill five additional exploration wells in the 2010–2011 winter drilling season.

Progress continued on the Mackenzie Gas project, which includes the development of three fields (ExxonMobil and Imperial Oil hold interests in two of the three fields) containing approximately 6 trillion gross cubic feet of natural gas. The project will deliver natural gas to North American markets through a 740-mile pipeline system to be built along the Mackenzie Valley. The National Energy Board approved the project, with conditions, in late 2010.

South America

Brazil

ExxonMobil operates Block BM-S-22, located approximately 220 miles south of Rio de Janeiro in the sub-salt play of the Santos Basin offshore Brazil (ExxonMobil interest 40 percent). BM-S-22 is a 342,000-acre block in water depths over 7400 feet.

The acquisition and processing of a 3D seismic survey was completed in 2010 and exploration studies are ongoing. A third well was drilled in 2010 and we are evaluating our data.

Colombia

ExxonMobil holds a Technical Evaluation Agreement for Block CPE-3 covering 6.4 million acres onshore Colombia. The block is located in a remote and unexplored area of the eastern Llanos Basin on trend with the Orinoco heavy oil belt. Plans are under way to acquire 2D seismic data and drill stratigraphic core holes in order to evaluate the prospectivity of this block.

Venezuela

The Cerro Negro and La Ceiba assets of ExxonMobil affiliates were expropriated without compensation by Venezuela on June 27, 2007. Prior to expropriation, ExxonMobil affiliates owned a 41⅔-percent interest in Cerro Negro and a 50-percent interest in La Ceiba. ExxonMobil filed an arbitration petition against Venezuela with the International Centre for Settlement of Investment Disputes (ICSID) in September 2007.

The ICSID Tribunal hearing is planned for 2012. ExxonMobil also filed an arbitration petition against Venezuela’s national oil company (PdVSA) with the International Chamber of Commerce (ICC) in January 2008. The ICC hearings concluded in September 2010, with a decision from the ICC anticipated in 2011.

Other South America

In Argentina, ExxonMobil holds a 51-percent interest in the Chihuidos concession and a 23-percent interest in the Aguarague concession. In 2010, net daily gas production of 52 million cubic feet was sold into markets in Argentina. In 2010, ExxonMobil acquired 130,000 net acres in the Neuquen Province through license rounds and joint ventures. Exploration drilling is being planned for 2012.

The company also holds exploration rights in the Stabroek block offshore Guyana. Processing of a recently acquired 2D seismic survey over the block is ongoing.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

EUROPE

ExxonMobil is one of the largest producers of oil and gas in Europe. Key assets include an extensive portfolio of North Sea oil and natural gas production operations and significant onshore natural gas production. In 2010, Europe accounted for 22 percent of net oil and gas production and 16 percent of Upstream earnings.

In our North Sea and onshore natural gas operations, we continue to progress exploration, additional projects, and increased recovery from producing assets through work programs and implementation of new technology.

Frontier exploration activity is progressing. In 2010, we participated in a well in the Turkish sector of the Black Sea, and have more activity planned in 2011. ExxonMobil continued to progress the evaluation of our significant unconventional gas opportunities in Germany and Poland.

It was the first full year of operation of our liquefied natural gas (LNG) receiving terminals in the United Kingdom and Italy, successfully providing additional gas supply to the European market.

Norway

ExxonMobil is among the largest oil and gas producers in Norway with average net production of 246 thousand barrels of liquids per day and 700 million cubic feet of gas per day in 2010.


Europe Highlights	2010		2009		2008

Earnings (billions of dollars)		3.8		3.6		9.9
Proved Reserves (BOEB)		2.9		3.2		3.4
Acreage (gross acres, million)		43.1		35.2		27.0
Net Liquids Production (MBD)		0.3		0.4		0.4
Net Gas Available for Sale (BCFD)		3.8		3.7		4.0

Europe Production

(millions of oil-equivalent barrels per day, net)

In 2010, Europe contributed

22%

of Upstream production

ExxonMobil operates producing fields in Norway including Ringhorne (ExxonMobil interest, 100 percent), Ringhorne East (ExxonMobil interest, 77 percent), and Balder (ExxonMobil interest, 100 percent), which are located 110 miles west of Stavanger. Since coming onstream in 2003, Ringhorne has produced over 200 million oil-equivalent barrels, and in 2010 production averaged 46 thousand oil-equivalent barrels per day. In 2010, ExxonMobil recommenced drilling operations from the Ringhorne platform following the successful 322-square-kilometer 4D state-of-the-art seismic program over the Balder and Ringhorne area. A drilling program is also anticipated to commence in the Balder Field in 2012.

ExxonMobil is a partner in 22 co-venturer-operated fields with active drilling programs in many core areas including the Ormen Lange field (ExxonMobil interest, 7 percent). Gas from the Ormen Lange field has been flowing since September 2007, and record production levels of 2.5 billion cubic feet per day were achieved in October 2010.

The Tyrihans field (ExxonMobil interest, 12 percent), located in the Norwegian Sea, reached peak production in 2010.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Tyrihans production in 2010 averaged 70 thousand barrels of oil per day from seven subsea wells tied back to the Kristin platform. Drilling will continue through 2011 to complete the planned 11-well subsea development.

ExxonMobil is operator of Production License 520 (ExxonMobil interest, 50 percent) in the Norwegian Sea. The license covers 736,000 acres in water depths ranging from 4200 to 8200 feet. In 2010, a 3D seismic survey was acquired over the license, which included a multi-azimuth test to improve seismic imaging. Seismic processing is now under way. ExxonMobil is also progressing conceptual engineering on Dagny and Luva offshore projects.

ExxonMobil is progressing frontier exploration activity in Europe, testing both onshore unconventional opportunities and offshore deepwater prospects.

United Kingdom

ExxonMobil is one of the largest oil and gas producers in the United Kingdom with average net production of 80 thousand barrels of liquids per day and 550 million cubic feet of gas per day in 2010.

ExxonMobil operates eight fields in the northern North Sea and has interests in more than 35 other producing fields that are co-venturer-operated. In 2010, ExxonMobil continued drilling operations from the Beryl Alpha platform (ExxonMobil interest, 50 percent) and mobilized a semisubmersible drilling rig to access opportunities using existing subsea infrastructure. The drilling programs, which will continue through at least 2012, are focused on maximizing value and recovery from this resource of 2.7 billion barrels originally in place, and extending field life.

ExxonMobil is the operator of the Scottish Area Gas Evacuation (SAGE) plant at St. Fergus and the SAGE pipeline that transports gas from the Beryl and Brae area fields to the plant. The company’s operations at Beryl and the SAGE gas plant are key contributors to U.K. energy supply. ExxonMobil is also progressing conceptual engineering on the Fram offshore project.

The South Hook LNG regasification terminal (ExxonMobil interest, 24 percent) located in Milford Haven, Wales, reached full capacity in April 2010, achieving peak daily rates of 2 billion cubic feet per day. A total of 78 LNG cargoes were delivered during 2010, totaling 8.2 million tonnes of gas into the U.K. grid.

Germany

ExxonMobil is Germany’s largest gas producer with average net production of 545 million cubic feet per day in 2010. A total of 55 ExxonMobil-operated fields account for approximately 70 percent of all natural gas produced in the country.

In 2010, ExxonMobil successfully completed major turnarounds at the Grossenkneten and NEAG sour gas processing plants. In addition, ExxonMobil completed a series of upgrades to the large compressor stations used to maximize field production and resource recovery. In 2010, ExxonMobil employed up to three drilling rigs targeting conventional and unconventional opportunities and deploying a broad range of technologies including proppant hydraulic fracturing programs.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

ExxonMobil holds six exploration licenses in the states of Lower Saxony and North Rhine Westphalia, in Germany. The licenses cover 3.2 million acres of the Lower Saxony, Ibbenburen, and Ruhr Basins, and include potential shale gas and coal bed methane exploration plays. ExxonMobil operates all of these licenses, with a 67-percent interest in five of them, and a 100-percent interest in the sixth. Ongoing exploration drilling is planned to continue into 2011 in order to evaluate a number of unconventional play concepts.

The Netherlands

ExxonMobil is one of the largest gas producers in the Netherlands, primarily through our shareholding in NAM (Nederlandse Aardolie Maatschappij), a 50-percent ExxonMobil equity company that produces gas from more than 100 fields located both onshore and offshore. In 2010, ExxonMobil’s net production averaged 2 billion cubic feet of gas per day. The majority of this production comes from the Groningen field (ExxonMobil interest, 30 percent) which is Europe’s largest natural gas field.

NAM’s Schoonebeek Redevelopment project (ExxonMobil interest, 30 percent) came online in early 2011. This enhanced oil recovery steam flood project, located in eastern Netherlands, includes a 120-megawatt cogeneration plant, and is expected to recover 120 million barrels of oil.

Italy

Adriatic LNG Terminal • The Adriatic LNG Terminal (ExxonMobil interest, 69 percent) located 10 miles offshore of Porto Levante, Italy, in the northern Adriatic Sea, is the world’s first fixed offshore LNG storage and regasification terminal. The terminal has capacity to supply up to 775 million cubic feet of gas per day to the Italian market, approximately 10 percent of Italy’s gas demand. In 2010, a total of 81 cargoes were delivered totaling 5.5 million tonnes of LNG.

Tempa Rossa • The Tempa Rossa project (ExxonMobil interest, 25 percent) in southern Italy includes a centralized oil and gas processing facility and a separate liquefied petroleum gas (LPG) terminal with new storage and offloading facilities. Upon completion, this project will produce a peak rate of 50 thousand barrels of oil per day along with associated natural gas and LPG. Appraisal drilling and contracting activities are progressing. The project is expected to develop over 200 million oil-equivalent barrels.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Ireland

ExxonMobil has interests in four exploration licenses (Cuchulain 36-percent interest; Dunquin 40-percent interest; and two Drombeg licenses at 80-percent interest) covering almost 1.5 million acres in the Porcupine Basin, which is a frontier area approximately 125 miles off the southwestern coast of Ireland. Evaluation activities continued across the area and a drilling site survey was acquired on the ExxonMobil-operated Dunquin license in 2010.

Romania

ExxonMobil has a 50-percent interest in the 1.8-million-acre deepwater Neptun Block in the Black Sea. A 3D seismic survey was acquired in 2009 and processed in 2010. Following the evaluation of the 3D seismic data, ExxonMobil and our partner will decide whether to participate in an exploratory drilling program.

Turkey

In 2009, ExxonMobil acquired an interest in two large exploration licenses in the Turkish Black Sea. The licenses cover more than 7 million acres in water depths ranging from 450 to 7250 feet. ExxonMobil operates the licenses with a 50-percent interest. In 2009, 2D and 3D seismic data were acquired. In 2010, we used our R³M electromagnetic technology to acquire additional subsurface images in the Black Sea. These data sets will be used to identify potential drilling opportunities on License 3921. Drilling on the ExxonMobil-operated licenses is anticipated to begin in 2011. In 2010, the co-venturer-operated Sinop-1 wildcat was the first well drilled on License 3922.

Poland

ExxonMobil has continued to build a large operated acreage position in the Podlasie and Lublin Basins of eastern Poland, the location of a potential new shale gas play. Additional licenses have been acquired, raising total holdings to more than 1.6 million acres (ExxonMobil interest, 100 percent). Acquisition has begun on the initial seismic program and drilling has commenced on the first of two exploration wells.

Greenland

In the West Disko area offshore western Greenland, ExxonMobil has interests in Block 6 (ExxonMobil interest, 44 percent) and Block 4 (ExxonMobil interest, 29 percent) totaling nearly 6.7 million gross acres. Evaluation activities continued across the blocks in 2010.

ExxonMobil has established a significant acreage position in the Black Sea and has an active exploration program under way.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

AFRICA

ExxonMobil is one of the leading oil producers in Africa. Our operations there accounted for 14 percent of our 2010 net production and 18 percent of total Upstream earnings.

In addition to our producing activities, ExxonMobil has ongoing African exploration operations. ExxonMobil holds interests in 23 deepwater blocks offshore Africa totaling almost 15 million acres, and participated in three deepwater exploration wells in 2010. We are also progressing liquefied natural gas opportunities in the region.

Angola

We have interests in four deepwater blocks covering 2.7 million acres. ExxonMobil and our co-venturers have announced a total of 63 discoveries in Angola, representing world-class development opportunities with a recoverable resource potential of approximately 14 billion oil-equivalent barrels. Including production from the co-venturer-operated Block 17, ExxonMobil’s net production in Angola averaged 141 thousand barrels of oil per day in 2010 with several new projects under construction or at the development planning stage.

Block 15 • ExxonMobil was awarded Block 15 in 1994 (ExxonMobil interest, 40 percent), and the first discovery was made in 1998. To date, a total resource of approximately 5 billion oil-equivalent barrels has been discovered on the block. First oil was produced in November 2003 from the Xikomba field, followed by start-ups of Kizomba A in 2004, Kizomba B in 2005, and Kizomba C in 2008. With a daily output of more than 520 thousand barrels of oil, it was Angola’s highest producing block during the year, and the facilities continue to operate with very high reliability.

Additional Block 15 developments continue to progress including the Gas Gathering project and Kizomba Satellites projects.


Africa Highlights	2010		2009		2008

Earnings (billions of dollars)		4.4		3.9		6.4
Proved Reserves (BOEB)		2.0		2.1		2.3
Acreage (gross acres, million)		16.5		17.7		42.4
Net Liquids Production (MBD)		0.6		0.7		0.6
Net Gas Available for Sale (BCFD)		–		–		–

Africa Production

(millions of oil-equivalent barrels per day, net)

Africa contributed more than

18%

of Upstream earnings

The Gas Gathering project commenced on-block gas handling in 2010 and is anticipated to collect and transport block-wide associated gas to the Angola LNG facility in Soyo in 2011. Execution activities are progressing on the Kizomba Satellites Phase 1 project that will include subsea tiebacks to the Kizomba A and B floating production, storage, and offloading (FPSO) vessels. The project is expected to recover nearly 250 million barrels of oil and is anticipated to start production in 2012. Through collaborative development efforts, ExxonMobil continues to utilize the local workforce to enhance Angolan industrial capabilities and competitiveness. Planning for development continues to progress for several of the remaining discovered resources on Block 15, including the Kizomba Satellites Phase 2 and 2009 Mondo South discovery.

Block 17 • ExxonMobil owns a 20-percent interest in Block 17, where oil was first discovered in 1996. Through year-end 2010, 15 discoveries have been announced on the block with a recoverable resource potential of approximately 6 billion oil-equivalent barrels. During 2010, production averaged 431 thousand barrels of oil per day from the Girassol, Dalia, and Rosa projects.

Project execution continues on Pazflor (ExxonMobil interest, 20 percent) in preparation for the anticipated 2011 start-up. The Pazflor project is located 100 miles offshore in 2600 feet

of water and will use an FPSO vessel to produce 200 thousand barrels of oil per day. The next development within Block 17 is Cravo-Lirio-Orquidea-Violeta (CLOV) (ExxonMobil interest, 20 percent), which was sanctioned by project co-venturers and began project execution in 2010. CLOV is expected to produce 160 thousand barrels of oil per day and will use a separate FPSO vessel.

ExxonMobil has three major project
start-ups in Angola in the next few years. (MAP)

Block 31 • ExxonMobil was awarded a 25-percent interest in Block 31 in 1999, and the first discovery was made in 2002. Through year-end 2010, 19 discoveries have been announced with a total resource of approximately 2 billion oil-equivalent barrels. The first development is the Plutao-Saturno-Venus-Marte (PSVM) hub located in the northern part of the block in water depths ranging from 5900 to 6700 feet. A single, 150-thousand-barrel-per-day FPSO vessel is under construction to produce an estimated 490 million barrels of oil. Planning is progressing for the development of an additional hub in the southeastern and central part of the block.

Block 32 • Planning activities on Block 32 continue to progress where ExxonMobil holds a 15-percent interest. Through year-end 2010, 12 discoveries have been announced with a total resource of approximately 1.4 billion oil-equivalent barrels on the block. The first FPSO vessel development being planned is the AB32 Kaombo Split Hub in the southeastern part of the block, with an estimated resource of up to 600 million barrels of oil. The water depth ranges from 4700 to 5600 feet. An appraisal well is planned in 2011.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Nigeria

ExxonMobil continues to develop our interest in offshore Nigeria both in shallow and deepwater acreage. ExxonMobil operates a shallow water joint venture with the Nigerian National Petroleum Corporation offshore southeastern Nigeria (ExxonMobil interest, 40 percent for crude and condensate; 51 percent for natural gas liquids) and the deepwater Erha and Erha North fields (under production sharing contracts). In addition, ExxonMobil also produces from the co-venturer-operated Bonga and Amenam/Kpono fields offshore Nigeria. Development drilling and project activities using Nigeria’s expanding capability are under way to further develop ExxonMobil’s interest. In 2010, ExxonMobil’s net production offshore Nigeria averaged 391 thousand barrels of liquids per day.

Nigeria – Deepwater

Erha/Erha North • The Erha development (ExxonMobil interest, 56 percent) is located 60 miles offshore in 3900 feet of water. Erha and Erha North started up in 2006 and delivered ExxonMobil’s first operated deepwater production in Nigeria. The combined development consists of more than 30 subsea wells tied back to a floating production, storage, and offloading vessel, with a capacity exceeding 200 thousand barrels per day.

The Erha North Phase 2 project (ExxonMobil interest, 56 percent) is a subsea tieback to the existing Erha floating production, storage, and offloading vessel. The project will further develop the currently producing Erha North field, with a peak production rate of 50 thousand barrels of oil per day. Contracting activities are advancing.

Bosi • The Bosi development (ExxonMobil interest, 56 percent) is planned as a subsea tieback to a spread-moored floating production, storage, and offloading vessel. Bosi project phases are expected to develop approximately 500 million barrels of oil and up to 2.5 trillion cubic feet of gas. Project concept selection stage activities are progressing.

Bonga North and Northwest • Bonga North and Bonga Northwest (ExxonMobil interest, 20 percent) are planned as subsea tiebacks to the existing Bonga Main FPSO vessel, which began production from the Bonga field in 2005. Project execution continues to progress on Bonga Northwest, and front-end engineering and design continue on Bonga North. These two projects combined will develop approximately 500 million barrels of oil.

Bonga Southwest • The Bonga Southwest project (ExxonMobil interest, 16 percent) is planned as an FPSO vessel development with a dedicated gas export pipeline. The project is anticipated to develop more than 800 million barrels of oil. Concept evaluation studies are progressing.

OML 138/Usan • Project execution continues on the Usan project (ExxonMobil interest, 30 percent) located 60 miles offshore Nigeria in 2500 feet of water. The complete development including future phases is designed to recover up to 500 million barrels of oil using subsea wells connected to a 180-thousand-barrel-per-day capacity FPSO vessel. Major contracts were awarded in early 2008 and development drilling and offshore installation were progressed in 2010. Exploration and development drilling is planned for 2011 and 2012.

OPL 233 • Following the Owowo South-1 discovery in 2009, ExxonMobil entered into the second exploration phase in OPL 223 (ExxonMobil interest, 27 percent) beginning in July 2010. Exploration drilling is planned for 2011 and 2012.

OPL 214 • ExxonMobil was awarded operatorship of OPL 214 in 2001 (ExxonMobil interest, 20 percent) and discovered the Uge field in 2005. Development planning for Uge continues and Phase III exploration drilling is planned in 2011.

Nigeria Shelf – Joint Venture

Across our portfolio of 69 discovered fields, an active development drilling program, installation of new platforms, enhanced oil recovery projects, and a series of platform upgrades continue to build liquid volumes. Seismic and exploration activity continues to find new opportunities within the joint venture. In 2009, the lease was extended for 20 years, with renewal rights for an additional 20 years.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Nigeria Natural Gas Liquids • The extraction of natural gas liquids in Nigeria is commercializing the associated gas production while enhancing oil recovery. Natural gas liquids production began in 1998 with the OSO Natural Gas Liquids project, and grew with the addition of the East Area Natural Gas Liquids II project (ExxonMobil interest, 51 percent) in 2008. Their production averaged 40 thousand barrels per day in 2010. These projects are expected to recover about 400 million barrels of natural gas liquids. Natural gas liquids plants along with pressure maintenance projects throughout the field will significantly reduce flaring and greenhouse gas emissions, and improve oil recovery through reservoir pressure maintenance.

Satellite Field Development • Execution of the “design one, build multiple” approach for the Satellite Field Development project (ExxonMobil interest, 40 percent) is progressing. Phase 1 is under way with installation of three platforms scheduled for 2011. These platforms will allow drilling in undeveloped or underdeveloped fields with pipeline connections back to existing infrastructure. Peak production from Phase 1 is anticipated to be 70 thousand barrels of liquids per day.

Domestic Power Generation and Natural Gas Supply • In 2010, ExxonMobil continued the front-end engineering and design work for a joint venture project to construct a 500-megawatt power plant. The project is a component of an integrated plan to increase gas utilization and power generation capacity in Nigeria. In addition, the joint venture is constructing new facilities that will allow for near-term delivery of approximately 100 million cubic feet of natural gas per day to the domestic market.

Equatorial Guinea

ExxonMobil operates the Zafiro field (ExxonMobil interest, 71 percent) in water depths between 400 and 2800 feet. In 2010, net production averaged 53 thousand barrels of oil per day. A two-rig drilling program was initiated in 2010, with one rig expected to continue drilling into 2011. ExxonMobil continues to progress discussions with the Equatorial Guinea government on projects aimed at enabling both a reduction in flaring and the development of Zafiro gas resources.

Chad

ExxonMobil began production in 2003 and continued to be the leading producer in Chad, with average net production of 43 thousand barrels of oil per day (ExxonMobil interest, 40 percent) in 2010. An active three-rig development drilling program continued in 2010, focused on the Kome and Miandoum fields.

Republic of Congo

Through year-end 2010, five discoveries have been announced in the Mer Tres Profonde Sud block (ExxonMobil interest, 30 percent) with a total resource of approximately 500 million oil-equivalent barrels. Additional exploration activity is planned.

Madagascar

ExxonMobil holds interests in approximately 1.3 million net acres in the Majunga Basin offshore Madagascar.

Libya

In 2010, ExxonMobil completed drilling a deepwater exploration well in Contract Area 44 and subsequently relinquished the area having fulfilled all work commitments. Exploration studies continue in Contract Areas 20 and 21 to determine the remaining prospectivity.

Tanzania

In 2010, ExxonMobil acquired equity in the deepwater Tanzania Block 2 (ExxonMobil interest, 35 percent). A 3D seismic survey was acquired in 2010 and is currently being interpreted in advance of a potential 2011 exploration well.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

ASIA

In Asia, our production grew significantly in 2010 with the ramp-up of the Qatar projects. In this region, we are participating in the development of some of the world’s largest oil and gas developments. In 2010, ExxonMobil’s operations in the Asia region contributed 34 percent of net oil and gas production and 39 percent of Upstream earnings.

Qatar

Through our Qatar joint ventures, Qatar Petroleum and ExxonMobil continue to develop the North Field, the largest non-associated gas field in the world, and will develop resources exceeding 25 billion oil-equivalent barrels through a suite of projects. The North Field is well-positioned to competitively supply liquefied natural gas (LNG) to the major markets in Asia, Europe, and North America. In 2009 and 2010, our joint ventures started up four of the world’s largest LNG trains, each with a production capacity of 7.8 million tonnes per year. These have more than doubled our LNG production capacity in Qatar and are making a significant contribution towards meeting the world’s growing energy demand. ExxonMobil participates in all of the RasGas trains and five Qatargas trains (ExxonMobil interest ranges from 10 to 34 percent). LNG production from ExxonMobil-interest trains in Qatar was 56 million tonnes in 2010. The Al Khaleej Gas facilities produced 1477 million cubic feet per day in 2010 and primarily supply the domestic market.

Qatargas • ExxonMobil participates in the Qatargas 1 and Qatargas 2 joint ventures with interests ranging from 10 to 30 percent. Qatargas 1 consists of three trains with a total capacity of 9.9 million tonnes per year, delivering LNG primarily to Japan and Spain.


Asia Highlights	2010		2009		2008

Earnings (billions of dollars)		9.4		5.2		8.5
Proved Reserves (BOEB)		8.6		9.1		9.8
Acreage (gross acres, million)		31.4		32.9		16.8
Net Liquids Production (MBD)		0.7		0.6		0.6
Net Gas Available for Sale (BCFD)		4.8		3.3		2.9

Asia Production

(millions of oil-equivalent barrels per day, net)

In 2010, Asia contributed

39%

of Upstream earnings

Qatargas 2 consists of two 7.8-million-tonne-per-year trains, which started up in 2009. These operations also produce associated products including condensate, liquefied petroleum gas (LPG), helium, and sulfur. Deliveries of LNG from Qatargas 2 use a fleet of Q-Flex and Q-Max vessels, the world’s largest LNG carriers. Shipments are being delivered primarily to the United Kingdom through the South Hook LNG Terminal.

RasGas • RasGas is a joint operating company comprised of Qatar Petroleum and ExxonMobil, with 70-percent and 30-percent interests respectively. The 7.8-million-tonne-per-year Train 7 started up in 2010 increasing total RasGas LNG production capacity to 37 million tonnes per year. LNG from the seven trains is distributed to the United States, Europe, and Asia markets. In addition to LNG, RasGas also produces considerable associated products including condensate, liquefied petroleum gas, helium, and sulfur.

Al Khaleej Gas • The Al Khaleej Gas Phase 1 and 2 project facilities are meeting the growing Qatar domestic demand. The first phase started up in 2005 (ExxonMobil interest, 100 percent), and the second-phase project started up in 2009 (ExxonMobil interest, 80 percent pending final agreement). The combined capacity of these facilities is now 2 billion cubic feet per day. Natural gas liquids recovery, including ethane sales to the domestic market, started up in 2010.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Common Facilities • RasGas and Qatargas participate in a range of common facilities for the storage and loading of LNG, condensate, liquefied petroleum gas, and sulfur on behalf of the Ras Laffan Industrial City joint venture companies. The utilization of shared facilities enables each participant to benefit from significant economies of scale.

Barzan • In 2007, Qatar Petroleum and ExxonMobil signed a heads of agreement to jointly develop all future phases of the Barzan project. In January 2011, a joint venture agreement, and development and fiscal agreement were signed for the initial phase of the Barzan project. This phase will supply up to 1.4 billion cubic feet per day of domestic gas to meet Qatar’s rapidly growing infrastructure and industry requirements. Front-end engineering and design activities are complete on the initial phase of the Barzan project, and the project is under way.

United Arab Emirates

ExxonMobil participates in two oil concessions in the United Arab Emirates. In 2010, the daily net production from the onshore oil concession was 119 thousand barrels of oil per day. Net production from the Upper Zakum offshore concession was 127 thousand barrels of oil per day.

Through our ability to deliver superior technology and execution excellence, ExxonMobil gained entry in 2006 into Upper Zakum (ExxonMobil interest, 28 percent). Upper Zakum is one of the world’s largest oil fields, with approximately 50 billion barrels of oil originally in place. The offshore Upper Zakum field covers more than 450 square miles and has production capacity of more than 550

thousand barrels per day. Through efforts with the joint venture, ExxonMobil is applying leading-edge technology that will boost daily field production capacity by an additional 200 thousand barrels per day. Construction has commenced on artificial islands that will utilize extended-reach drilling to boost recovery at a lower cost.

Iraq

In January 2010, ExxonMobil signed a contract with the South Oil Company (SOC) of the Iraqi Ministry of Oil to redevelop and expand the West Qurna (Phase I) oil field (ExxonMobil interest, 60 percent) in southern Iraq. In August 2010, it was agreed to increase the target production capacity through development of additional reservoirs.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

In Iraq and the United Arab Emirates, our experience and leading-edge technologies are being applied to some of the largest oil fields in the world.

The contract area contains more than 300 wells and is located in one of Iraq’s most prolific producing areas. Redevelopment of the field will require extensive in-fill drilling, reservoir pressure support, new production facilities, and associated support infrastructure. ExxonMobil’s technologies and execution experience in these areas ensure we are well-positioned to maximize the value of this resource.

Since signing, ExxonMobil has established a presence in both Basra and Baghdad and has awarded early contracts for drilling, well workovers, and field maintenance services. At year-end 2010, activity was under way to establish a working field camp and offices to house the new field operating division. In accordance with the contract, we are working with the SOC to form a new Field Operating Division in 2011, which will manage the planning, surveillance, and day-to-day conduct of petroleum operations in the field.

ExxonMobil continues to deliver excellent project execution and field operation in challenging arctic conditions.

Russia

ExxonMobil operates and holds a 30-percent interest in the Sakhalin-1 project, which comprises the Chayvo, Odoptu, and Arkutun-Dagi fields. The Sakhalin-1 project is one of the largest foreign investment projects in Russia and is being developed in phases.

Sakhalin-1 Chayvo and Odoptu • In 2005, first oil production and gas sales to far east Russia commenced from the initial development phase of the Chayvo field. In 2010, the daily production averaged 144 thousand barrels of oil and 153 million cubic feet of sales gas. Since the initial Sakhalin-1 start-up in 2005, almost 300 million barrels of oil have been produced and exported to world markets.

In 2010, the next phase of the Sakhalin-1 project, Odoptu (ExxonMobil interest, 30 percent), started up. The Odoptu development utilized the Yastreb, one of the world’s most powerful land-based rigs, to drill eight extended-reach wells, with one additional well to be completed in 2011. These wells reach up to 7 miles offshore.

Sakhalin-1 Future Phases • The future project to develop the Arkutun-Dagi field phase was fully funded in 2010 and continues to advance early fabrication activities. Major contracts have been awarded and construction has commenced on the gravity-based structure platform.

Supported by a heads of agreement signed with China National Petroleum Corporation (CNPC) in 2006, we continued to work towards gas pipeline sales from Sakhalin-1 to China. Other regional gas sales options, including domestic gas markets, continue to be evaluated.

Azerbaijan

ExxonMobil has an interest in the Azeri-Chirag-Gunashli (ACG) megafield (ExxonMobil interest, 8 percent). Initial start-up of the Chirag platform in 1997 was followed by Phases 1 and 2 of the Azeri field in 2005 and 2006, respectively, with Phase 3 from the deepwater Gunashli field commencing in 2008. Production continues at plateau with an active ongoing drilling program. Since initial start-up in 1997, over 1.6 billion barrels of oil have been produced. In 2010, the ACG field achieved oil production rates in excess of 850 thousand barrels per day. Development of a sixth platform was initiated in 2010 that will add a further 115 thousand barrels per day to existing volumes.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Kazakhstan

Tengiz • ExxonMobil participates in the Tengizchevroil (TCO) joint venture (ExxonMobil interest, 25 percent), which includes a production license area encompassing the giant Tengiz field, an associated processing plant complex, and the nearby Korolev field. Including an exploration license adjacent to the production area, TCO holds a total of 608,000 acres. The Tengiz field has produced more than 1.6 billion barrels of oil from a resource of nearly 6 billion barrels. In 2010, TCO achieved record production rates in excess of 625 thousand barrels of oil per day as the recently completed major expansion reached full rate. The TCO joint venture continues to invest in projects to improve the reliability and integrity of the existing facilities and is progressing the early definition of a potential further major expansion project.

Kashagan • As a participant in the North Caspian Production Sharing Agreement (ExxonMobil interest, 17 percent), ExxonMobil continues to work with partners to progress phased development of the massive Kashagan field located offshore in the Caspian Sea. Phase 1 includes an offshore production and separation hub on an artificial island, several drilling islands, and an onshore processing plant. The first phase is anticipated to produce 3.6 billion barrels of oil at a production rate of 360 thousand barrels per day.

Full development is expected to increase recovery up to 12 billion barrels of oil at a production rate of approximately 1.5 million barrels of oil per day. ExxonMobil is leading drilling operations and subsurface planning for Phase 2 and future phases.

Caspian Pipeline Consortium • The Caspian Pipeline Consortium (ExxonMobil interest, 8 percent), achieved full shareholder approval of an expansion project that will increase the system capacity from 0.6 to 1.4 million barrels per day from Kazakhstan to the Novorossiysk marine terminal on the Russian Black Sea coast by 2015. This system is the lowest-cost export option for Kazakhstan, with both Tengizchevroil and the future Kashagan developments as major shippers.

Indonesia

ExxonMobil operates the onshore Arun field and Arun satellite fields, and the North Sumatra Offshore field. These fields supply gas to the PT Arun LNG plant. In 2010, net production averaged 215 million cubic feet of gas per day plus associated liquids.

Early oil production on the Banyu Urip development in the Cepu Contract Area, onshore Java (ExxonMobil interest, 45 percent) commenced in 2009 with the capacity to produce approximately 20 thousand barrels of oil per day. Full-field development is progressing to produce 165 thousand barrels of oil per day and is planned to include 49 wells, an onshore central processing facility, and a 60-mile pipeline to transport the processed oil to a floating storage and offloading vessel. Land acquisition and major contract-tendering activities continue to progress for the full project. ExxonMobil completed a successful exploration well in 2010. Additional Cepu exploration drilling is planned for 2011.

In 2008, ExxonMobil submitted a Plan of Development for the large offshore gas field, containing over 70 percent carbon dioxide, within the Natuna D-Alpha Block and communicated intent to the Indonesia government to enter the next phase of development. Development has continued on key project technical and execution aspects under the Plan of Development. In 2010, ExxonMobil signed a heads of agreement with Pertamina that provides a framework for negotiation of a new production sharing contract with the government of Indonesia.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

ExxonMobil completed two deepwater exploration wells in the Makassar Straits Mandar block (ExxonMobil interest, 80 percent) in 2010. Analysis of the results is ongoing. Exploration drilling is anticipated to commence on the coal bed methane production sharing contracts (ExxonMobil interest, 49 percent) in early 2011, followed by pilot testing. Also in 2010, ExxonMobil acquired a 1200-square-kilometer 3D seismic survey on the Cendrawasih block.

Malaysia

ExxonMobil operates 43 platforms in 17 fields and is one of Malaysia’s major suppliers of crude oil and natural gas. Net production in 2010 averaged 48 thousand barrels of liquids per day and 513 million cubic feet of gas per day. In 2010, ExxonMobil successfully installed four new full well-stream subsea pipelines to extend the life of the Seligi and Semangkok fields.

ExxonMobil is well-positioned to meet growing regional energy demands with significant project and exploration activity in Asia Pacific.

During 2010, design work progressed on the Tapis field enhanced oil recovery project. In addition, ExxonMobil is pursuing a Guntong field enhanced oil recovery project. Early development planning work has begun for this project. ExxonMobil is also progressing the Damar Gas and Telok projects, which will provide additional gas supplies for Malaysia’s power and industrial needs.

Philippines

During 2009 and 2010, ExxonMobil completed four deepwater exploration wells on the SC-56 Block (ExxonMobil interest, 50 percent). Gas was discovered in three of the four wells, and the data is being analyzed to determine future plans.

Vietnam

ExxonMobil acquired interest in several blocks offshore Vietnam in 2009, totaling more than 13 million net acres. Drilling of an offshore Vietnam exploration well is anticipated in 2011, and planning is under way to commence a 1,500-square-kilometer 3D seismic survey.

Hong Kong Power

Through a partnership with CLP Holdings (China Light and Power), ExxonMobil has a 60-percent interest in the Castle Peak Power Company, located in Hong Kong, with 6900 megawatts of power generation capacity; and a 51-percent interest in 600 megawatts of pumped storage capacity in southern China. In 2010, a major air emissions reduction project was brought into service at the Castle Peak power station to align with the current emissions cap.

AUSTRALIA/OCEANIA

In 2010, ExxonMobil’s operations in the Australia/Oceania region contributed 3 percent of net oil and gas production and 3 percent of Upstream earnings. The future contribution from this region is anticipated to grow even more with the start-up of the PNG and Gorgon Jansz LNG projects.

Australia


Australia/Oceania Highlights	2010		2009		2008

Earnings (billions of dollars)		0.6		0.6		0.8
Proved Reserves (BOEB)		1.5		1.5		0.6
Acreage (gross acres, million)		7.1		11.7		12.6
Net Liquids Production (MBD)		0.1		0.1		0.1
Net Gas Available for Sale (BCFD)		0.3		0.3		0.3

Australia/Oceania Production

(millions of oil-equivalent barrels per day, net)

ExxonMobil is a leading oil and gas producer in Australia. In 2010, net production averaged 51 thousand barrels of liquids and 332 million cubic feet of gas per day. The majority of current production is from the offshore Gippsland Basin.

New developments under way in the Gippsland Basin include the Kipper Tuna Turrum project (ExxonMobil interest, Kipper 32.5 percent, Tuna and Turrum 50 percent). During 2010, the first two Kipper wells were drilled and each successfully tested at over 45 million cubic feet of gas per day.

In 2010, ExxonMobil discovered two new Gippsland Basin fields: Southeast Remora and Southeast Longtom. Evaluation of these discoveries and future satellite developments is ongoing.

Execution activities continue on the 15-million-tonne-per-year Gorgon Jansz liquefied natural gas (LNG) project (ExxonMobil interest, 25 percent), to develop 25 trillion cubic

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

feet of offshore gas resources. The development consists of subsea infrastructure for offshore production and transportation of the gas, three 5-million-tonne-per-year LNG trains, and a 280-million-cubic-feet-per-day domestic gas plant located on Barrow Island, as well as the world’s largest carbon dioxide sequestration project to minimize emissions. The ExxonMobil-operated Jansz field development drilling program will be produced via one of the world’s longest subsea tiebacks, located in 4300 feet of water. The first Gorgon Jansz LNG shipment is targeted for late 2014.

In 2010, ExxonMobil participated in numerous exploration and appraisal activities in the greater Gorgon area, including a gas discovery on the Northwest Shelf, in block WA-392-P (ExxonMobil interest, 25 percent). Planning for development of more than 15 trillion cubic feet (gross) of additional offshore gas resources in the Greater Gorgon Area satellite fields will continue in 2011, including additional appraisal drilling. ExxonMobil was also awarded the WA-444-P block east of the Gorgon Jansz discoveries.

Development and execution planning continues to progress for the Scarborough LNG project (ExxonMobil interest, 50 percent). The field is located offshore Western Australia in 3100 feet of water and has a resource of up to 10 trillion cubic feel of gas.

Papua New Guinea (PNG)

In 2010, ExxonMobil’s net production from Papua New Guinea averaged 7 thousand barrels of oil per day. Since obtaining 2009 approval for developing the PNG liquefied natural gas project (ExxonMobil interest, 33 percent), all major engineering, procurement, and construction contracts have been awarded, and project execution is under way including infrastructure development to improve accessibility. The project will develop the Hides, Angore, and Juha fields (IMAGE)

as well as process gas from the existing Kutubai, Gobe, and Moran oil fields. The development includes a 6.6-million-tonne-per-year LNG facility located near Port Moresby, conditioning facilities in the PNG Southern Highlands, and approximately 450 miles of onshore and offshore pipelines. In 2010, the national trainee program commenced at the new Production Operations Training Center to build the future workforce for the development.

Also in 2010, ExxonMobil commenced acquisition of a multiyear 2D seismic program in the PNG Highlands in advance of potential 2011 and 2012 exploration drilling programs.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Upstream Operating Statistics

NET LIQUIDS PRODUCTION⁽¹⁾ – Including Oil Sands and Non-Consolidated Operations


(thousands of barrels per day)	2010		2009		2008		2007		2006

United States
Alaska		117		123		130		132		127
Lower 48		291		261		237		260		287
Total United States		408		384		367		392		414
Canada/South America		263		267		292		324		354
Total Americas		671		651		659		716		768

Europe
United Kingdom		80		90		123		150		186
Norway		246		280		295		319		320
Other		9		9		10		11		14
Total Europe		335		379		428		480		520

Africa
Nigeria		391		391		364		415		427
Angola		141		194		181		173		193
Equatorial Guinea		53		55		60		76		103
Other		43		45		47		53		58
Total Africa		628		685		652		717		781

Asia
Malaysia		48		52		56		67		64
Middle East		478		368		381		374		340
Russia/Caspian		191		182		160		185		127
Other		13		5		2		3		4
Total Asia		730		607		599		629		535

Australia/Oceania		58		65		67		74		77

Total worldwide		2,422		2,387		2,405		2,616		2,681


Gas Plant Liquids Included Above
United States		59		50		49		57		61
Non-U.S.		207		173		164		166		175

Total worldwide		266		223		213		223		236


Oil Sands and Non-Consolidated Volumes Included Above
United States		69		73		78		82		87
Canada/South America – Bitumen		115		120		124		130		127
Canada/South America – Synthetic Oil		67		65		62		65		58
Europe		5		5		5		6		6
Asia		404		320		280		265		243

Total worldwide		660		583		549		548		521


(1)		Net liquids production quantities are the volumes of crude oil and natural gas liquids withdrawn from ExxonMobil’s oil and gas reserves, excluding royalties and quantities due to others when produced, and are based on the volumes delivered from the lease or at the point measured for royalty and/or severance tax purposes. Volumes include 100 percent of the production of majority-owned affiliates, including liquids production from oil sands operations in Canada, and ExxonMobil’s ownership of the production by companies owned 50 percent or less.



(1) Royal Dutch Shell, BP, and Chevron values are calculated on a consistent basis with ExxonMobil, based on public information.
(2) 2010 competitor data not available.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

NET NATURAL GAS PRODUCTION AVAILABLE FOR SALE⁽¹⁾ – Including Non-Consolidated Operations


(millions of cubic feet per day)	2010		2009		2008		2007		2006

United States		2,596		1,275		1,246		1,468		1,625
Canada/South America		569		643		640		808		935
Total Americas		3,165		1,918		1,886		2,276		2,560

Europe
The Netherlands		2,041		1,676		1,748		1,551		1,536
United Kingdom		550		594		750		779		990
Norway		700		786		764		705		686
Germany		545		633		687		775		874
Total Europe		3,836		3,689		3,949		3,810		4,086

Africa		14		19		32		26		–

Asia
Indonesia		215		245		239		286		365
Malaysia		513		545		582		583		519
Middle East		3,865		2,367		1,911		1,875		1,353
Russia/Caspian		187		153		114		110		92
Other		21		22		24		29		29
Total Asia		4,801		3,332		2,870		2,883		2,358

Australia/Oceania		332		315		358		389		330

Total worldwide		12,148		9,273		9,095		9,384		9,334


Non-Consolidated Natural Gas Volumes Included Above
United States		1		1		1		1		1
Europe		1,977		1,618		1,696		1,503		1,500
Asia		2,954		1,918		1,433		1,351		1,075

Total worldwide		4,932		3,537		3,130		2,855		2,576


(1)		Net natural gas available for sale quantities are the volumes withdrawn from ExxonMobil’s natural gas reserves, excluding royalties and volumes due to others when produced, and excluding gas purchased from others, gas consumed in producing operations, field processing plant losses, volumes used for gas lift, gas injection and cycling operations, quantities flared, and volume shrinkage due to the removal of condensate or natural gas liquids fractions.

NATURAL GAS SALES⁽¹⁾


(millions of cubic feet per day)	2010		2009		2008		2007		2006

United States		3,166		1,321		1,292		1,560		1,686
Canada/South America		696		739		845		968		1,120
Europe		6,401		5,854		5,665		5,396		5,728
Africa		14		19		32		26		–
Asia		4,102		2,760		2,612		2,631		2,153
Australia/Oceania		339		322		366		398		338

Total worldwide		14,718		11,015		10,812		10,979		11,025


(1)		Natural gas sales include 100 percent of the sales of ExxonMobil- and majority-owned affiliates and ExxonMobil’s ownership of sales by companies owned 50 percent or less. Numbers include sales of gas purchased from third parties.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

NUMBER OF NET WELLS DRILLED ANNUALLY⁽¹⁾


(net wells drilled)	2010		2009		2008		2007		2006

Productive
Exploratory⁽²⁾		37		20		19		19		21
Development		1,200		829		731		917		1,041

Total		1,237		849		750		936		1,062


Dry
Exploratory⁽²⁾		7		9		9		16		12
Development		5		5		4		19		11

Total		12		14		13		35		23


Net Wells Drilled
Exploratory⁽²⁾		44		29		28		35		33
Development		1,205		834		735		936		1,052

Total		1,249		863		763		971		1,085

NET ACREAGE AT YEAR END⁽³⁾


(thousands of net acres)	2010		2009		2008		2007		2006

Undeveloped
United States		4,914		5,111		5,691		5,539		6,062
Canada/South America		11,977		17,107		19,953		22,563		22,224
Europe		16,118		13,470		7,913		6,002		2,727
Africa		8,612		10,555		26,439		24,835		24,075
Asia		19,086		20,457		6,824		7,715		6,739
Australia/Oceania		1,352		5,216		5,738		5,844		1,172

Total worldwide		62,059		71,916		72,558		72,498		62,999


Developed
United States		9,919		5,120		5,148		5,174		5,178
Canada/South America		2,439		2,460		2,488		2,366		2,360
Europe		2,986		3,806		4,026		4,194		4,418
Africa		684		758		756		729		717
Asia		1,271		1,160		1,048		1,037		1,033
Australia/Oceania		719		719		719		728		738

Total worldwide		18,018		14,023		14,185		14,228		14,444

NET CAPITALIZED COSTS AT YEAR END⁽³⁾


(millions of dollars)	2010		2009		2008		2007		2006

United States		70,011		20,363		18,542		16,948		16,530
Canada/South America		18,089		13,408		9,967		11,338		10,076
Europe		12,845		14,357		11,477		15,426		15,182
Africa		22,563		20,917		17,797		15,149		14,280
Asia		23,765		21,859		19,191		17,186		14,759
Australia/Oceania		5,284		3,725		2,407		2,630		2,300

Total worldwide		152,557		94,629		79,381		78,677		73,127


(1)		A regional breakout of this data is included on pages 13 and 14 of ExxonMobil’s 2010 Form 10-K.

(2)		These include near-field and appraisal wells classified as exploratory for SEC reporting.

(3)		Includes non-consolidated interests and Canadian oil sands operations.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

COSTS INCURRED IN PROPERTY ACQUISITION, EXPLORATION, AND DEVELOPMENT ACTIVITIES⁽¹⁾


	Property
	Acquisition		Exploration		Development		Total
(millions of dollars)	Costs		Costs		Costs		Costs

During 2010
United States		45,143		694		8,270		54,107
Canada/South America		136		527		4,757		5,420
Europe		64		606		1,452		2,122
Africa		3		453		4,390		4,846
Asia		115		547		3,195		3,857
Australia/Oceania		–		228		1,146		1,374

Total worldwide		45,461		3,055		23,210		71,726


During 2009
United States		205		549		2,787		3,541
Canada/South America		353		498		2,394		3,245
Europe		1		525		3,639		4,165
Africa		605		880		4,596		6,081
Asia		121		529		2,946		3,596
Australia/Oceania		–		130		768		898

Total worldwide		1,285		3,111		17,130		21,526


During 2008
United States		281		453		2,739		3,473
Canada/South America		126		325		1,421		1,872
Europe		25		401		1,863		2,289
Africa		82		686		4,783		5,551
Asia		73		307		3,384		3,764
Australia/Oceania		76		100		443		619

Total worldwide		663		2,272		14,633		17,568


During 2007
United States		63		377		1,859		2,299
Canada/South America		93		231		902		1,226
Europe		–		229		2,016		2,245
Africa		13		584		2,847		3,444
Asia		21		210		3,721		3,952
Australia/Oceania		4		131		225		360

Total worldwide		194		1,762		11,570		13,526


During 2006
United States		54		382		1,838		2,274
Canada/South America		100		225		1,002		1,327
Europe		11		202		2,660		2,873
Africa		16		518		3,433		3,967
Asia		416		295		2,942		3,653
Australia/Oceania		–		63		228		291

Total worldwide		597		1,685		12,103		14,385


(1)		Includes non-consolidated interests and Canadian oil sands operations.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

PROVED OIL AND GAS RESERVES⁽¹⁾


	2010		2009		2008		2007		2006

Liquids, Including Oil Sands and Non-Consolidated Reserves (millions of barrels at year end)
Net proved developed and undeveloped reserves
United States		2,303		1,972		1,971		2,225		2,275
Canada/South America		2,946		2,918		2,683		1,633		2,113
Europe		454		517		560		699		760
Africa		1,799		1,907		2,137		2,058		2,089
Asia		3,896		4,049		4,424		4,246		4,112
Australia/Oceania		275		288		231		213		219

Total worldwide		11,673		11,651		12,006		11,074		11,568


Proportional interest in oil sands and non-consolidated reserves included above
United States		351		356		327		374		391
Canada/South America (bitumen)⁽²⁾		2,102		2,055		1,767		717		741
Canada/South America (synthetic oil)⁽²⁾		681		691		734		694		718
Europe		31		30		27		26		12
Asia		1,873		2,050		2,205		2,236		2,253
Net proved developed reserves included above
United States		1,749		1,490		1,521		1,626		1,777
Canada/South America		1,333		1,311		1,315		1,376		1,620
Europe		382		386		419		526		568
Africa		1,055		1,122		1,284		1,202		1,279
Asia		2,929		2,876		2,514		2,214		2,172
Australia/Oceania		139		153		165		185		200

Total worldwide		7,587		7,338		7,218		7,129		7,616


Natural Gas, Including Non-Consolidated Reserves (billions of cubic feet at year end)
Net proved developed and undeveloped reserves
United States		26,111		11,802		11,890		13,297		12,180
Canada/South America		1,258		1,368		1,383		1,559		1,984
Europe		14,788		16,173		17,284		18,853		19,640
Africa		908		920		918		1,006		986
Asia		28,399		30,304		32,383		31,790		31,059
Australia/Oceania		7,351		7,440		2,021		1,757		1,711

Total worldwide		78,815		68,007		65,879		68,262		67,560


Proportional interest in non-consolidated reserves included above
United States		117		114		112		125		131
Europe		10,746		11,450		11,839		12,341		12,551
Asia		21,139		22,001		22,526		23,186		22,398
Net proved developed reserves included above
United States		15,441		7,582		7,931		8,477		9,389
Canada/South America		1,077		1,200		1,148		1,303		1,628
Europe		11,683		12,782		13,710		14,743		15,331
Africa		711		739		738		773		823
Asia		27,087		25,206		17,876		14,021		13,542
Australia/Oceania		1,174		1,262		1,346		1,403		1,504

Total worldwide		57,173		48,771		42,749		40,720		42,217


(1)		ExxonMobil reserves using SEC historical price bases; proved reserves as defined by the SEC are based on historical market prices: prior to 2009, the SEC defined price as the market price on December 31; beginning in 2009, the SEC changed the definition to the average of the market prices on the first day of each calendar month during the year. Mining and equity company reserves are included for all periods. See Frequently Used Terms on pages 98 through 101.

(2)		Proved reserves classified as bitumen are associated with the Cold Lake and Kearl projects in Canada. Proved reserves classified as synthetic oil are associated with the Syncrude project in Canada. Cold Lake uses in situ methods, and hydrocarbons are produced from wells drilled into the subsurface. Syncrude is an oil sands mining project which includes an upgrader that converts the mined hydrocarbons into a higher gravity crude oil. Kearl is an oil sands mining project that does not incorporate an upgrader.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

PROVED OIL AND GAS RESERVES⁽¹⁾


	2010		2009		2008		2007		2006

Oil-Equivalent, Including Oil Sands and Non-Consolidated Reserves (millions of barrels at year end)
Net proved developed and undeveloped reserves
United States		6,654		3,939		3,953		4,441		4,305
Canada/South America		3,155		3,146		2,914		1,893		2,444
Europe		2,919		3,212		3,441		3,841		4,034
Africa		1,951		2,060		2,290		2,226		2,253
Asia		8,630		9,100		9,820		9,544		9,288
Australia/Oceania		1,500		1,528		568		506		504

Total worldwide		24,809		22,985		22,986		22,451		22,828

PROVED OIL AND GAS RESERVES REPLACEMENT⁽¹⁾⁽²⁾


(million barrels of oil or billion cubic feet of gas																Average
unless specified otherwise)	2010			2009			2008			2007			2006			2006-2010

Liquids (millions of barrels)
Revisions		358			361			583			666			442			482
Improved recovery		5			15			6			35			27			17
Extensions/discoveries		185			142			1,308			194			186			403
Purchases		378			–			–			–			746			225
Sales		(21	)		(3	)		(86	)		(436	)		(86	)		(126	)

Total additions		905			515			1,811			459			1,315			1,001
Production		883			870			879			953			976			912

Reserves replacement ratio, excluding sales (percent)		105			60			216			94			144			124
Reserves replacement ratio, including sales (percent)		102			59			206			48			135			110


Natural Gas (billions of cubic feet)
Revisions		879			135			643			4,435			1,466			1,512
Improved recovery		–			–			1			4			13			3
Extensions/discoveries		1,988			5,694			692			324			2,957			2,331
Purchases		12,789			8			–			9			57			2,572
Sales		(106	)		(13	)		(82	)		(320	)		(104	)		(125	)

Total additions		15,550			5,824			1,254			4,452			4,389			6,293
Production		4,742			3,696			3,637			3,750			3,736			3,912

Reserves replacement ratio, excluding sales (percent)		330			158			37			127			120			164
Reserves replacement ratio, including sales (percent)		328			158			34			119			117			161


Oil-Equivalent (millions of barrels)
Revisions		505			383			690			1,405			687			734
Improved recovery		5			15			7			36			29			18
Extensions/discoveries		516			1,091			1,423			248			679			791
Purchases		2,510			1			–			2			755			654
Sales		(38	)		(5	)		(100	)		(490	)		(104	)		(147	)

Total additions		3,498			1,485			2,020			1,201			2,046			2,050
Production		1,674			1,486			1,485			1,578			1,598			1,564

Reserves replacement ratio, excluding sales (percent)		211			100			143			107			135			140
Reserves replacement ratio, including sales (percent)		209			100			136			76			128			131


(1)		ExxonMobil reserves using SEC historical price bases; proved reserves as defined by the SEC are based on historical market prices: prior to 2009, the SEC defined price as the market price on December 31; beginning in 2009, the SEC changed the definition to the average of the market prices on the first day of each calendar month during the year. Mining and equity company reserves and production are included for all periods. See Frequently Used Terms on pages 98 through 101.

(2)		The term “sales” includes the impact of expropriation of proved reserves in Venezuela (462 million oil-equivalent barrels) in 2007.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW


2010 RESERVES CHANGES BY REGION⁽¹⁾

	Crude Oil and Natural Gas Liquids																					Bitumen		Synthetic Oil
				Canada/																		Canada/		Canada/
(million barrels of oil or billion cubic feet of gas	United			South												Australia/						South		South			Liquids
unless specified otherwise)	States			America			Europe			Africa			Asia			Oceania			Total			America		America			Total

Liquids (millions of barrels)
Revisions		74			10			56			89			19			7			255			89		14			358
Improved recovery		4			–			–			–			–			1			5			–		–			5
Extensions/discoveries		46			11			4			34			90			–			185			–		–			185
Purchases		374			–			–			–			4			–			378			–		–			378
Sales		(19	)		–			–			(2	)		–			–			(21	)		–		–			(21	)

Total additions		479			21			60			121			113			8			802			89		14			905
Production		148			30			123			229			266			21			817			42		24			883
Net change		331			(9	)		(63	)		(108	)		(153	)		(13	)		(15	)		47		(10	)		22

Reserves replacement ratio, excluding sales (percent)		336			70			49			54			42			38			101			212		58			105
Reserves replacement ratio, including sales (percent)		324			70			49			53			42			38			98			212		58			102


Natural Gas (billions of cubic feet)
Revisions		840			123			(30	)		6			(102	)		42			879
Improved recovery		–			–			–			–			–			–			–
Extensions/discoveries		1,861			3			73			25			25			1			1,988
Purchases		12,774			–			15			–			–			–			12,789
Sales		(104	)		(2	)		–			–			–			–			(106	)

Total additions		15,371			124			58			31			(77	)		43			15,550
Production		1,062			234			1,443			43			1,828			132			4,742
Net change		14,309			(110	)		(1,385	)		(12	)		(1,905	)		(89	)		10,808

Reserves replacement ratio, excluding sales (percent)		1,457			54			4			72			–			33			330
Reserves replacement ratio, including sales (percent)		1,447			53			4			72			–			33			328


(1)		See Frequently Used Terms on pages 98 through 101.

Proved Reserves Distribution

By Region

(percent, billions of oil-equivalent barrels, year-end 2010)

Proved Reserves Distribution

By Type

(percent, billions of oil-equivalent barrels, year-end 2010)

We have a diverse global reserves portfolio, and our reserves are approximately evenly distributed between oil and gas.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

PROVED OIL AND GAS RESERVES REPLACEMENT⁽¹⁾


(million barrels of oil or billion cubic feet of gas													Average
unless specified otherwise)	2010		2009		2008			2007		2006			2006–2010

Non-U.S.
E&P costs (millions of dollars)		17,619		17,985		14,095			11,227		12,111			14,607

Liquids reserves additions		426		375		1,933			368		1,417			904
Liquids production		735		731		747			812		827			770

Gas reserves additions		179		5,340		2,099			2,685		5,319			3,124
Gas production		3,680		3,124		3,075			3,101		3,018			3,200

Oil-equivalent reserves additions, excluding sales		459		1,266		2,377			1,293		2,357			1,550
Oil-equivalent reserves additions, including sales		456		1,264		2,283			815		2,303			1,424
Oil-equivalent production		1,348		1,252		1,259			1,329		1,330			1,304

Reserves replacement ratio, excluding sales (percent)		34		101		189			97		177			119
Reserves replacement ratio, including sales (percent)		34		101		181			61		173			109
Reserves replacement costs⁽²⁾ (dollars per barrel)		38.39		14.21		5.93			8.68		5.14			9.42


United States
E&P costs (millions of dollars)		54,107		3,541		3,473			2,299		2,274			13,139

Liquids reserves additions		479		140		(122	)		91		(102	)		97
Liquids production		148		139		132			141		149			142

Gas reserves additions		15,371		484		(845	)		1,767		(930	)		3,169
Gas production		1,062		572		562			649		718			713

Oil-equivalent reserves additions, excluding sales		3,077		224		(257	)		398		(207	)		647
Oil-equivalent reserves additions, including sales		3,041		221		(263	)		386		(257	)		626
Oil-equivalent production		325		234		226			249		268			260

Reserves replacement ratio, excluding sales (percent)		947		96		–			160		–			248
Reserves replacement ratio, including sales (percent)		936		94		–			155		–			240
Reserves replacement costs⁽²⁾ (dollars per barrel)		17.58		15.81		–			5.78		–			20.31


Worldwide
E&P costs (millions of dollars)		71,726		21,526		17,568			13,526		14,385			27,746

Liquids reserves additions		905		515		1,811			459		1,315			1,001
Liquids production		883		870		879			953		976			912

Gas reserves additions		15,550		5,824		1,254			4,452		4,389			6,293
Gas production		4,742		3,696		3,637			3,750		3,736			3,912

Oil-equivalent reserves additions, excluding sales		3,536		1,490		2,120			1,691		2,150			2,197
Oil-equivalent reserves additions, including sales		3,497		1,485		2,020			1,201		2,046			2,050
Oil-equivalent production		1,673		1,486		1,485			1,578		1,598			1,564

Reserves replacement ratio, excluding sales (percent)		211		100		143			107		135			140
Reserves replacement ratio, including sales (percent)		209		100		136			76		128			131
Reserves replacement costs⁽²⁾ (dollars per barrel)		20.28		14.45		8.29			8.00		6.69			12.63


(1)		ExxonMobil reserves using SEC historical price bases; proved reserves as defined by the SEC are based on historical market prices: prior to 2009, the SEC defined price as the market price on December 31; beginning in 2009, the SEC changed the definition to the average of the market prices on the first day of each calendar month during the year. Mining and equity company reserves, production, and costs are included for all periods. See Frequently Used Terms on pages 98 through 101.

(2)		Calculation based on exploration and production costs divided by oil-equivalent reserves additions. All values exclude the impact of asset sales; i.e., reserves sold and proceeds received.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

OIL AND GAS EXPLORATION AND PRODUCTION EARNINGS

The revenue, cost, and earnings data are shown both on a total dollar and a unit basis, and are inclusive of non-consolidated and Canadian oil sands operations.


	Total Revenues and Costs, Including Non-Consolidated Interests and Oil Sands																		Revenues and Costs per Unit of Sales or Production⁽¹⁾
				Canada/																	Canada/
	United			South										Australia/					United		South			Outside
	States			America			Europe		Africa		Asia			Oceania			Total		States		America			Americas		Worldwide


2010	(millions of dollars)																		(dollars per unit of sales)
Revenue
Liquids		10,567			6,343			8,935		17,511		19,118			1,418			63,892		70.98		66.27			74.67		73.12
Natural gas		3,716			707			9,358		11		7,990			401			22,183		3.92		3.41			5.42		5.00



																			(dollars per barrel of net oil-equivalent production)
Total revenue		14,283			7,050			18,293		17,522		27,108			1,819			86,075		46.53		54.18			54.59		53.04
Less costs:
Production costs excluding taxes		3,275			2,612			3,011		2,215		1,628			462			13,203		10.67		20.07			6.17		8.14
Depreciation and depletion		3,507			1,015			2,719		2,580		1,596			219			11,636		11.43		7.80			6.00		7.17
Exploration expenses		287			464			413		587		362			56			2,169		0.94		3.57			1.20		1.34
Taxes other than income		1,220			86			2,997		1,742		5,142			204			11,391		3.96		0.67			8.49		7.02
Related income tax		2,093			715			5,543		6,068		9,147			262			23,828		6.82		5.49			17.73		14.68



Results of producing activities		3,901			2,158			3,610		4,330		9,233			616			23,848		12.71		16.58			15.00		14.69
Other earnings⁽²⁾		379			(538	)		216		96		(120	)		(15	)		18		1.23		(4.13	)		0.15		0.02



Total earnings, excluding power and coal		4,280			1,620			3,826		4,426		9,113			601			23,866		13.94		12.45			15.15		14.71
Power and coal		(8	)		–			–		–		239			–			231



Total earnings		4,272			1,620			3,826		4,426		9,352			601			24,097



2009	(millions of dollars)																		(dollars per unit of sales)
Revenue
Liquids		7,573			5,135			7,739		14,868		12,941			1,311			49,567		54.02		51.88			58.53		57.04
Natural gas		1,442			748			9,080		12		4,237			341			15,860		3.10		3.19			5.09		4.69



																			(dollars per barrel of net oil-equivalent production)

Total revenue		9,015			5,883			16,819		14,880		17,178			1,652			65,427		41.41		43.02			46.74		45.58
Less costs:
Production costs excluding taxes		2,736			2,428			2,923		2,027		1,498			386			11,998		12.57		17.75			6.32		8.36
Depreciation and depletion		1,833			948			2,246		2,293		1,182			195			8,697		8.42		6.93			5.47		6.06
Exploration expenses		220			339			387		662		393			33			2,034		1.01		2.48			1.36		1.42
Taxes other than income		767			78			2,826		1,343		3,111			252			8,377		3.52		0.57			6.97		5.83
Related income tax		1,127			597			5,179		4,667		5,943			237			17,750		5.18		4.37			14.83		12.37



Results of producing activities		2,332			1,493			3,258		3,888		5,051			549			16,571		10.71		10.92			11.79		11.54
Other earnings⁽²⁾		565			(605	)		325		81		(86	)		36			316		2.60		(4.43	)		0.33		0.22



Total earnings, excluding power and coal		2,897			888			3,583		3,969		4,965			585			16,887		13.31		6.49			12.12		11.76
Power and coal		(4	)		–			–		–		224			–			220



Total earnings		2,893			888			3,583		3,969		5,189			585			17,107


(1)		The per-unit data are divided into two sections: (a) revenue per unit of sales from ExxonMobil’s own production; and, (b) operating costs and earnings per unit of net oil-equivalent production. Units for crude oil and natural gas liquids are barrels, while units for natural gas are thousands of cubic feet. The volumes of crude oil and natural gas liquids production and net natural gas production available for sale used in this calculation are shown on pages 62 and 63. The volumes of natural gas were converted to oil-equivalent barrels based on a conversion factor of 6 thousand cubic feet per barrel.

(2)		Includes earnings related to transportation operations, LNG liquefaction and transportation operations, sale of third-party purchases, technical services agreements, other nonoperating activities, and adjustments for minority interests.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Oil and Gas Exploration and Production Earnings (continued)


	Total Revenues and Costs, Including Non-Consolidated Interests and Oil Sands																		Revenues and Costs per Unit of Sales or Production⁽¹⁾
				Canada/																	Canada/
	United			South										Australia/					United		South			Outside
	States			America			Europe		Africa		Asia			Oceania			Total		States		America			Americas		Worldwide


2008	(millions of dollars)																		(dollars per unit of sales)
Revenue
Liquids		11,788			8,540			13,910		20,606		20,288			2,111			77,243		87.95		81.43			91.66		89.84
Natural gas		3,296			1,834			15,230		39		7,005			389			27,793		7.23		7.82			8.59		8.35



																			(dollars per barrel of net oil-equivalent production)
Total revenue		15,084			10,374			29,140		20,645		27,293			2,500			105,036		71.73		71.23			73.74		73.19
Less costs:
Production costs excluding taxes		2,675			2,625			3,051		1,603		1,392			332			11,678		12.72		18.03			5.91		8.14
Depreciation and depletion		1,427			1,043			2,662		2,471		1,231			179			9,013		6.79		7.16			6.06		6.28
Exploration expenses		189			251			183		439		292			109			1,463		0.90		1.72			0.95		1.02
Taxes other than income		2,021			81			4,248		1,815		5,457			665			14,287		9.61		0.55			11.29		9.95
Related income tax		3,191			1,813			11,979		8,119		10,691			399			36,192		15.17		12.45			28.90		25.22



Results of producing activities		5,581			4,561			7,017		6,198		8,230			816			32,403		26.54		31.32			20.63		22.58
Other earnings⁽²⁾		687			(997	)		2,860		212		(45	)		29			2,746		3.27		(6.85	)		2.83		1.91



Total earnings, excluding power and coal		6,268			3,564			9,877		6,410		8,185			845			35,149		29.81		24.47			23.46		24.49
Power and coal		(25	)		–			–		–		278			–			253



Total earnings		6,243			3,564			9,877		6,410		8,463			845			35,402



2007	(millions of dollars)																		(dollars per unit of sales)
Revenue
Liquids		8,997			6,569			11,986		17,834		15,878			1,752			63,016		62.86		55.27			69.32		66.58
Natural gas		3,176			1,704			9,911		21		4,763			400			19,975		5.93		5.77			5.82		5.83



																			(dollars per barrel of net oil-equivalent production)
Total revenue		12,173			8,273			21,897		17,855		20,641			2,152			82,991		52.42		49.40			55.55		54.40
Less costs:
Production costs excluding taxes		2,275			2,206			3,243		1,180		1,163			266			10,333		9.80		13.17			5.20		6.77
Depreciation and depletion		1,493			1,256			2,657		2,101		1,229			172			8,908		6.43		7.50			5.47		5.85
Exploration expenses		282			273			170		470		205			102			1,502		1.21		1.63			0.84		0.98
Taxes other than income		1,347			126			2,528		1,599		3,561			570			9,731		5.80		0.75			7.33		6.38
Related income tax		2,429			1,190			8,190		7,263		8,140			331			27,543		10.46		7.11			21.25		18.05



Results of producing activities		4,347			3,222			5,109		5,242		6,343			711			24,974		18.72		19.24			15.46		16.37
Other earnings⁽²⁾		609			(504	)		944		277		(13	)		(1	)		1,312		2.62		(3.01	)		1.07		0.86



Total earnings, excluding power and coal		4,956			2,718			6,053		5,519		6,330			710			26,286		21.34		16.23			16.53		17.23
Power and coal		(86	)		–			–		–		297			–			211



Total earnings		4,870			2,718			6,053		5,519		6,627			710			26,497



2006	(millions of dollars)																		(dollars per unit of sales)
Revenue
Liquids		8,417			6,405			11,069		17,253		11,965			1,631			56,740		55.63		50.42			60.90		58.70
Natural gas		3,689			1,984			11,333		–		3,983			280			21,269		6.22		5.81			6.31		6.24



																			(dollars per barrel of net oil-equivalent production)
Total revenue		12,106			8,389			22,402		17,253		15,948			1,911			78,009		48.41		45.07			51.80		50.44
Less costs:
Production costs excluding taxes		2,367			2,075			2,669		965		881			244			9,201		9.46		11.15			4.29		5.95
Depreciation and depletion		1,264			1,123			2,354		2,096		976			144			7,957		5.06		6.03			5.02		5.14
Exploration expenses		247			172			169		330		243			30			1,191		0.99		0.92			0.70		0.77
Taxes other than income		833			146			2,885		1,612		4,688			426			10,590		3.33		0.79			8.66		6.85
Related income tax		2,711			1,258			8,667		6,878		4,919			364			24,797		10.84		6.76			18.76		16.03



Results of producing activities		4,684			3,615			5,658		5,372		4,241			703			24,273		18.73		19.42			14.37		15.70
Other earnings⁽²⁾		503			112			891		122		37			5			1,670		2.01		0.60			0.95		1.08



Total earnings, excluding power and coal		5,187			3,727			6,549		5,494		4,278			708			25,943		20.74		20.02			15.32		16.78
Power and coal		(19	)		–			–		–		306			–			287



Total earnings		5,168			3,727			6,549		5,494		4,584			708			26,230

See footnotes on page 70.

COMPETITIVE ADVANTAGES

Balanced Portfolio Quality • We are the world’s largest integrated refiner, manufacturer of lube basestocks, and a leading marketer of petroleum products. Our world-class facilities are located around the globe in major petroleum markets.

Disciplined Investing • We maintain a disciplined, long-term approach to managing capital employed. Our ongoing evaluation of our Downstream portfolio has resulted in investments in resilient, advantaged projects, while selectively divesting less attractive assets over the past several years.

High-Impact Technologies • Proprietary Molecule Management technology enables us to optimize raw material selection and processing, while maximizing yields of higher-value products.

Operational Excellence • Application of systematic processes and efficient execution have established us as an industry leader in operational excellence and cost effectiveness.

Global Integration • More than 75 percent of our refining capacity is integrated with our chemical and/or lubes operations. Our global functional organization facilitates efficient development and deployment of global best practices and new technologies.

Downstream

BUSINESS SEGMENT OVERVIEW

Refining & Supply • ExxonMobil is the world’s largest integrated refiner with a network of reliable and efficient refineries, marine vessels, pipelines, and distribution centers that provides transportation fuels, lube basestocks, chemical feedstocks, and other high-value products to our customers around the world.

Fuels Marketing • We create long-term value by selling high-quality products and services daily to millions of customers worldwide and providing secure, ratable, and profitable outlets for our refineries.

Lubricants & Specialties • ExxonMobil has a competitive advantage as the No. 1 supplier of lube basestocks and a market leader of high-technology, globally recognized synthetic lubricant brands.

BUSINESS ENVIRONMENT

By 2030, energy demand for transportation fuels is forecast to increase nearly 40 percent versus 2005. This increase will be driven by growth in developing countries, while demand in the more mature, developed markets is projected to be essentially flat as improvements in fuel economy and transportation system efficiencies offset demand from vehicle growth.

Despite the potential positive effects of this energy demand growth in our Downstream business, we expect the challenging business environment for refining to continue, reflecting the increase in global refining capacity and regulatory-related policies. However, ExxonMobil’s business model, coupled with our strengths, is designed to capture strong margins at the top of the business cycle and outperform competition at the bottom of the cycle. Our results demonstrate the resiliency of our business. Additionally, business restructuring and disciplined investments continue to position our businesses to capture growth opportunities worldwide over the long term. A good example of this is our ongoing migration to less capital-intensive fuels distribution channels like the branded wholesaler model in the United States.

Our Downstream strategies are effective across a range of industry conditions, and our success is due to our continued commitment to these strategies throughout the business cycle. The Downstream has continued to deliver industry-leading returns due, in large part, to strong operational performance, disciplined capital management, industry-leading level of integration, and leading-edge proprietary technologies.


DOWNSTREAM STATISTICAL RECAP	2010		2009		2008		2007		2006

Earnings (millions of dollars)		3,567		1,781		8,151		9,573		8,454

Refinery throughput (thousands of barrels per day)		5,253		5,350		5,416		5,571		5,603

Petroleum product sales (thousands of barrels per day)		6,414		6,428		6,761		7,099		7,247

Average capital employed⁽¹⁾ (millions of dollars)		24,130		25,099		25,627		25,314		23,628

Return on average capital employed⁽¹⁾ (percent)		14.8		7.1		31.8		37.8		35.8

Capital expenditures (millions of dollars)		2,505		3,196		3,529		3,303		2,729

(1) See Frequently Used Terms on pages 98 through 101.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Our Downstream business remains the industry’s most efficient, delivering the highest return on average capital employed compared to key international competitors.

RESULTS & HIGHLIGHTS

Industry-leading safety performance.

Zero hydrocarbon spills from owned/operated and long-term leased marine vessels.

Earnings were $3.6 billion, reflecting an improved business environment and continued margin and efficiency capture.

Return on average capital employed was 15 percent,
more than double 2009, and consistently leading industry throughout the business cycle.

Downstream capital expenditures were $2.5 billion,
including investments in growth markets, high-value products, efficiency improvement, and environmentally driven expenditures.

New facilities at our refineries in Baytown, Texas; Baton Rouge, Louisiana; and, Antwerp, Belgium were completed, increasing ultra-low sulfur diesel supply by 6 million gallons per day.

ExxonMobil and Synthetic Genomics Inc. (SGI) opened a greenhouse at SGI’s headquarters in La Jolla, California, to advance the next level of research and testing on algae biofuels.

6.4
million
barrels per day in
petroleum product
sales, including record
sales for Mobil 1
synthetic motor oil

The Downstream’s industry-leading return on average capital employed demonstrates the value of disciplined capital management, operational excellence, and the strength of our global brands.




(1) Royal Dutch Shell, BP, and Chevron values are estimated on a consistent basis with ExxonMobil, based on public information.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Maintain Best-in-Class Operations

Our focus on operational excellence extends to all parts of our business. It is the foundation for our “license to operate” and is fundamental to our competitive advantage.

Operational Excellence Personnel and operations safety remains our top priority, and our Operations Integrity Management System (OIMS) continues to provide the framework to ensure safe and reliable operations. The Downstream achieved industry-leading safety performance with low lost-time incident rates, and we continue to improve safety by focusing on human factors that cause most incidents. We are emphasizing personal safety awareness, accountability, and adherence to proven standards and practices supported by increasing field observations and training. For example, in our Lubricants and Specialties business, our driver safety program includes training to help employees avoid accidents. This program supports our goal that Nobody Gets Hurt, and we have achieved impressive results. In 2010, our accident rate was about 0.5 per million miles driven, equivalent to one accident per 150 years of driving for a typical U.S. motorist. In addition, we remain focused on effective deployment and sustainment of our Loss Prevention System, a standardized set of integrated behavior-based safety tools in use across our operations.

We are continuing to improve operations safety and reliability through ongoing activities to identify and reduce risks inherent in our businesses, while enhancing our facilities, systems, and worker competencies. For example, to continuously improve the skills of our workforce, we have developed a Global Manufacturing Training system for use across our manufacturing sites that will improve upon several existing training programs. We are also driving continuous improvement in several other areas that impact operations including equipment reliability, security,

Above everything else is our relentless focus on operational excellence: safety, security, health, environmental and controls performance.

environmental performance, and business controls. Progress is being achieved through selective investments, use of global management systems, best practice sharing, peer networks, and most importantly, through the commitment of our employees and contractors. These processes and their efficient execution have helped establish us as an industry leader in operational excellence.

Risk Management The Downstream business utilizes a disciplined safety risk identification and reduction system to identify, assess, and mitigate potential safety risks at our manufacturing facilities. This system helps direct resources to activities that enable us to maintain operational excellence at our manufacturing (IMAGE)

sites. To manage business risk, our marketing businesses have robust processes in place to effectively administer credit exposure. Disciplined credit practices and sound receivables management continue to reduce overall working capital employed, improving financial returns.

Largest Global Refiner


Refinery interests		36
Distillation capacity (barrels per day)		6.3 million
Lube basestock capacity (barrels per day)		131 thousand

Diverse Fuels Marketing Customer Base
with Global Reach


Branded service stations		~26,000
Commercial customers		~600,000

Global Lubricants Leadership Position


Market position		No. 1 supplier of lube basestocks
		and synthetic lubricants

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Provide Quality, Valued Products and Services to Our Customers

ExxonMobil Downstream provides fuels, lubricants, feedstocks, and other high-value products and services to our customers around the world. Our Fuels Marketing business provides a secure, ratable, and profitable outlet for our refineries and serves millions of customers daily around the world. In addition, we are the No. 1 supplier of lube basestocks and a market leader of synthetic lubricant products.

Manufacturing and Marketing High-Quality Products We strive to provide quality products to our customers. In order to achieve this, we have a Global Product Quality Management System (GPQMS) that spans our global operations and drives quality assurance throughout our production and distribution chain, from manufacturing to sales. GPQMS defines quality specifications for each product we manufacture or market and establishes the stewardship and compliance assessment processes to ensure consistent delivery of quality products. This integrated product quality management system, coupled with a strong refining and distribution network, positions us as a reliable supplier to a wide variety of customers around the world. We also leverage Molecule Management technology to ensure that highest-value products are produced. This is especially important at our integrated sites to ensure value is maximized across our fuels, lubricants, and chemical businesses. Our processing models enable us to optimize, at a molecular level, the entire manufacturing site as well as individual process units on a real-time basis to increase yields and the blending of higher-value products.

World-Class Brands Technology leadership, supply reliability, and customer trust underpin the commercial success of our brands. At the forefront of our high-technology finished lubricant brands are Mobil 1 and Mobil SHC. Major automotive and industrial equipment manufacturers trust us to deliver value through leading-edge technologies that protect engines and equipment. Our products help provide sustainability-related benefits such as energy efficiency, fuel economy, extended oil drain intervals, and equipment durability, while maintaining peak performance.

Our fuel products and services are brought to market through our four Fuels Marketing business lines: Retail, Industrial and Wholesale, Aviation, and Marine. These businesses provide flexibility to serve the needs of a diverse range of customers. In addition to the millions of customers that visit Exxon, Mobil, and Esso retail service stations around the world, our business-to-business channels supply a large customer portfolio that includes a wide range of industries, as well as multinational and local aviation and marine clients.


UpClose: Products with Unique Applications

ExxonMobil lubricants are used around the world in the most challenging applications and environments. For example, in 2010, 33 miners in Chile were rescued after being trapped more than 2000 feet underground for 69 days. The rescue had special meaning for ExxonMobil Lubricants and Specialties. The main drilling equipment used Mobil-branded lubricants to drill the shaft and enable the rescue capsule to descend and lift the miners to safety above the ground.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Lead Industry in Efficiency and Effectiveness

We achieve industry-leading cost performance by reducing energy use, leveraging our global scale and integration, and deploying our leading-edge technologies to generate cost efficiencies.

Cost Efficiencies ExxonMobil captures cost savings through economies of scale, centralized support activities, global work processes, and reliable operations. For example, we have shared organizations that support operations at our integrated refining and chemical sites, and we continue to progress our Global Manufacturing Training initiative to improve overall workforce productivity. We are also implementing new maintenance technologies to help improve productivity and reduce costs. We are able to supply our manufacturing sites with lower-cost materials and services by capitalizing on our purchasing scale, market intelligence, global best practices, and a strong partnership with other ExxonMobil business units.

Margin Improvement We improve margins by focusing on economically increasing production, reducing raw material costs, and capturing higher product realizations. We focus on maximizing the economic utilization of our existing refining capacity by improving reliability, eliminating operating constraints, and expanding market outlets. We continue to upgrade our facilities and apply technology to increase raw material processing flexibility and to produce higher-value products. For example, ExxonMobil is an industry leader in processing “challenged crudes,” running over 60 percent more than industry. These crudes are typically more difficult to handle or process because they have properties such as acid corrosivity, high nitrogen content, and other impurities. Because of these characteristics, these crudes are sold at a discount, providing a raw material cost advantage. Another measure of raw material flexibility is the number of crudes that are new to each refinery. In 2010, we processed 130 crudes new to individual sites.

Our marketing businesses continue to implement initiatives to achieve cost-efficiency improvements that have more than offset inflationary pressures over the last several years. Simultaneously, we are restructuring the business model towards more efficient and effective distribution channels. Since 2006, Fuels Marketing operating expenditures (at constant foreign exchange rates and energy price) have declined more than 15 percent. Our Lubes and Specialties business has become more efficient by consolidating customer service centers, rationalizing blend plants, and streamlining our product offering while continuing to capture high-value growth opportunities.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Energy Initiatives Energy represents about one-third of the operating cost of a manufacturing facility and remains a focus area for cost efficiency. For example, ExxonMobil’s proprietary Global Energy Management System focuses on opportunities that reduce

the energy consumed at our refineries, lube oil blend plants, and chemical sites. Since 2002, we have improved refinery energy efficiency by an average of 7.5 percent with a goal of achieving a 10-percent reduction by 2012 across our worldwide manufacturing operations. Improved energy efficiency is a key contributor to our cost performance, and we have consistently outpaced industry in this area.

To further optimize our energy consumption, we continue to make significant investments in cogeneration facilities that simultaneously produce electricity and useful heat or steam. With the latest technology, cogeneration is significantly more efficient than traditional methods of producing steam and power separately, and results in lower greenhouse gas (GHG) emissions and cost. Additionally, through an ongoing initiative of plant optimization and upgrading of high energy-consuming steam and compressed air equipment, we have reduced overall GHG emissions from our network of finished lube oil blend plants by nearly 20 percent since 2004.

UpClose: Sustainability

ExxonMobil recognizes the importance of addressing sustainability in today’s global marketplace. For example, in our Lubricants and Specialties business, we are reducing environmental impacts by improving

packaging design that reduces materials and transportation costs. An initiative to optimize the design of our motor oil bottles has enabled us to cut plastic and resin consumption by up to 25 percent. We are also developing leading-edge technology products which help to improve fuel economy, reduce emissions, and extend oil drain intervals.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Capitalize on Integration

Integration between business functions is a competitive advantage that delivers value through identification of attractive investment opportunities, implementation of best practices, application of advantaged technologies, and optimization of our operations.

Worldwide Optimization In the Downstream, we use an integrated approach to develop new business opportunities and optimize our global operations. For example, in support of the Upstream, our global supply organization manages the economic placement of over 2 million barrels per day of equity crude. At our manufacturing sites, we use computer models to optimize operations on an integrated basis to produce fuels products, chemicals, lubricants, and asphalts. Our refineries are more than 60-percent larger than the industry average with more conversion capacity and more integration with chemical and lubes operations.

Downstream cross-functional teams work together to improve the value of ExxonMobil’s refined products. Integrated Business Teams combine manufacturing, supply, technology, logistics, and marketing expertise to optimize margin capture and maximize shareholder value. These teams evaluate product placement alternatives in each market around the world, optimizing sales to higher-value channels. As a result, we have identified and implemented several initiatives to optimize domestic and export sales mix in several of our integrated markets. This has improved refinery and terminal utilization and helped us capture profitable domestic accounts for our Fuels Marketing business. Common work processes, tools, and analytical methodologies enable us to achieve these results. Integration across our businesses

Our global scale and level of integration are structural advantages that are difficult for competitors to replicate.

also allows us to capture benefits by sharing best practices. Using global support services as well as common systems and processes, we are able to leverage the expertise of our employees around the world.

EXXONMOBIL REFINERIES INTEGRATED WITH CHEMICAL AND/OR LUBES

More than 75 percent of our global refining capacity is integrated with chemical and/or lubes, and 100 percent of our lube basestocks manufacturing capacity is integrated with refining. This level of integration is unmatched in the industry and provides a significant competitive advantage.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Invest for Resilient, Advantaged Returns

ExxonMobil’s capital management strategy takes a disciplined and long-term approach to managing capital employed while sustaining industry-leading returns. This approach combines selective and resilient investments with disciplined capital and portfolio management to optimize the productivity and profitability of our business.

Selective and Resilient Investments ExxonMobil has a disciplined approach to investments to ensure our projects are advantaged to support growth and add value. For example, we have invested over $1 billion to increase supply of ultra-low sulfur diesel (ULSD) in support of forecasted long-term demand growth. In 2010, we completed facilities at our Baytown, Texas; Baton Rouge, Louisiana; and, Antwerp, Belgium, refineries to increase the supply of ULSD by more than 6 million gallons per day. In 2011, we anticipate providing additional supply of lower-sulfur gasoline and diesel with the

We are the most capital-efficient of our peer group, consistently generating advantaged returns on capital employed.

start-up of a SCANfining unit and a distillate hydrofiner upgrade at our Sriracha, Thailand, refinery. We have also invested in expansions and low-cost debottleneck projects to increase capacity and improve product yields at existing sites that generate attractive returns over a range of market conditions. Recently, we expanded hydrotreater capacity and distillate yield at our Port Jerome-Gravenchon, France, refinery. In addition, by building on our strengths, including supply reliability, product technology, and technical expertise, our Lubricants and Specialties business is well-positioned to grow in the high-value synthetics sectors and in developing markets such as China, India, and Russia. To sustain this growth, we continue to progress disciplined investments in blending capacity and branded marketing outlets, as well as leverage our world-class brands and relationships with equipment manufacturers.

Disciplined Capital Management We continue to take a disciplined approach to managing capital employed, including selective and resilient investments, asset divestments, and sound working capital practices. For example, in our Fuels Marketing business, we continue to reduce overall capital employed through sound accounts receivable management and portfolio highgrading. By consistently implementing this approach, the capital productivity of Fuels Marketing, defined as volume sold by unit of capital employed, has more than doubled since 2006.

UpClose: Disciplined Portfolio Management

We continuously evaluate our assets and take appropriate action to maximize long-term shareholder value. For example, during the stronger refining margin period a few years ago, we did not greatly expand our Downstream operations. Instead, we have been making changes to the Downstream portfolio on an ongoing basis.

Since 2000, we have divested our interest in 11 refineries, over 5000 miles of pipeline assets, about 140 product terminals, as well as a net reduction of about 40 lube oil blend plants and more than 20,000 retail sites.

In 2010, we sold our interest in the Dunkirk, France, lube oil refinery and continued to progress our retail restructuring activities to convert to a more efficient branded wholesaler model in the United States. These changes further enhance portfolio integration of our downstream assets.

We have reduced our capital employed since 2000 while the average of our competitors’ capital employed has increased.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Maximize Value from Leading-Edge Technology

ExxonMobil’s Downstream research and technology portfolio encompasses a broad range of activities to address business challenges. We focus on developing and deploying high-impact technologies that maximize the efficiency and value of our existing assets as well as identifying game-changing technologies to sustain competitive advantage in both conventional downstream and emerging areas.

Supply and Manufacturing Optimization ExxonMobil operates one of the world’s largest and most complex supply chains, executing manufacturing operations on a global scale. Technical experts throughout our organization use advanced optimization models to assist decision making in complex and time-constrained activities such as transportation scheduling. For example, we schedule ship voyages and cargo handling with models that include proprietary algorithms and advanced solvers that optimize loading and discharge operations to match supply availability with refinery capabilities, meeting our needs at the lowest cost.

We take advantage of real-time models to optimize our ability to efficiently meet product specifications within refinery product pools. Molecule-based models examine the trade-offs among potential blend streams from a variety of sources. These models optimize site distillation and conversion unit operations to maximize overall production of on-specification products like ultra-low sulfur diesel, ultimately enhancing product yield and refinery margins. Our fundamental technical advantages include detailed molecular characterization of feedstocks, intermediate streams, and products, along with strong expertise in process dynamics like fluid flow and heat transfer. These advantages underpin our ability to gain maximum value from optimization technologies.

Our fundamental molecular-level understanding drives advanced catalytic and modeling technologies that enable optimized refining operations, formulation of fuels that clean vital engine parts, and development of unique lubricants like Mobil 1 and Mobil SHC products.

Catalyst Discovery and Development Catalysts are key contributors to value capture by enabling cost-effective and efficient processing of petroleum products and petrochemicals. Since the 1940s, ExxonMobil has had a tradition of discovering, developing, and deploying new catalysts in processes such as Fluid Catalytic Cracking, hydrocracking, hydrotreating, lubricant dewaxing, and hydrofinishing. Recently, we have applied high throughput experimentation tools to accelerate new catalyst discovery. These efforts are leading to improved catalysts with the ability to process heavier feedstocks and to tolerate increased levels of catalyst deactivators like nitrogen and sulfur, while maintaining high-conversion activity to make desired products. We are continuing to enhance these industry-leading catalyst discovery capabilities by using state-of-the-art quantum chemical and molecular modeling techniques. These approaches provide us with a fundamental understanding of factors influencing the effectiveness of catalysts. When coupled with our molecule-based refinery process modeling, this enables us to further accelerate the development of improved catalysts.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Improving Energy Efficiency To improve lubricant efficiency, our researchers are using new molecules and advanced formulations to develop next-generation lubricants that protect surfaces while allowing dramatic reductions in machinery operating temperatures, a key factor in significantly improving oil and equipment life. We are also delivering leading-edge technology to customers through lubricant products that reduce fuel consumption and provide longer oil life, such as Mobil SHC Pegasus gas engine oil and Mobil DTE Excel hydraulic oil. At our refineries, we use technology to minimize our energy consumption much like we optimize our use of molecules, through comprehensive monitoring and tools to improve decision making. We also actively seek to minimize fouling of surfaces that transfer heat between process streams. Through molecular understanding of crude oil composition, it is possible to select feed blends with inherent capability to reduce fouling. By reducing fouling, we improve heat transfer efficiency, which decreases the overall heat requirements for processing. This reduces furnace firing and greenhouse gas emissions.

Algae Biofuels With the opening of a new greenhouse research and testing facility in La Jolla, California, ExxonMobil Research and Engineering Company and Synthetic Genomics Inc. (SGI) have entered an important second stage in the collaboration to develop strains of algae that could produce refinery feedstock and transportation fuels. The high-tech greenhouse supplements ongoing laboratory activity with additional research in a more real-world environment. Here, scientists and engineers experiment with different algae growth systems, light levels, temperature conditions,

carbon dioxide amounts, and nutrient concentrations to better evaluate whether large-scale volumes of affordable biofuel can be made from algae. They will also identify the most robust strains, naturally occurring and engineered, that exhibit the optimal, sought-after characteristics of growth, bio-oil composition, and recoverability.

This work is a long-term initiative, and ExxonMobil and SGI have made good progress to date. SGI has isolated and developed a large number of candidate algae strains and identified conditions under which the strains can be made more productive. ExxonMobil has evaluated various production technologies and is assessing which approaches have the greatest commercial potential. The next phase is to build a larger outdoor test facility. Work on this facility has already begun in parallel with the research now being advanced in the greenhouse, and it is anticipated to open in mid-2011.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Downstream Operating Statistics

THROUGHPUT, CAPACITY, AND UTILIZATION⁽¹⁾


	2010		2009		2008		2007		2006

Refinery Throughput⁽²⁾ (thousands of barrels per day)
United States		1,753		1,767		1,702		1,746		1,760
Canada		444		413		446		442		442
Europe		1,538		1,548		1,601		1,642		1,672
Japan		536		556		563		618		649
Asia Pacific excluding Japan		713		772		789		798		785
Middle East/Latin America/Other		269		294		315		325		295

Total worldwide		5,253		5,350		5,416		5,571		5,603


Average Refinery Capacity⁽³⁾ (thousands of barrels per day)
United States		1,962		1,970		1,967		1,963		1,957
Canada		505		502		502		502		502
Europe		1,744		1,742		1,740		1,759		1,817
Japan		681		680		702		769		769
Asia Pacific excluding Japan		1,030		1,006		992		983		971
Middle East/Latin America/Other		331		331		330		330		329

Total worldwide		6,253		6,231		6,233		6,306		6,345


Utilization of Refining Capacity (percent)
United States		89		90		87		89		90
Canada		88		82		89		88		88
Europe		88		89		92		93		92
Japan		79		82		80		80		84
Asia Pacific excluding Japan		69		77		80		81		81
Middle East/Latin America/Other		81		89		95		98		90

Total worldwide		84		86		87		88		88


(1)		Excludes ExxonMobil’s interest in the Laffan Refinery in Qatar and ExxonMobil’s minor interests in certain small refineries.

(2)		Refinery throughput includes 100 percent of crude oil and feedstocks sent directly to atmospheric distillation units in operations of ExxonMobil and majority-owned subsidiaries. For companies owned 50 percent or less, throughput includes the greater of either crude and feedstocks processed for ExxonMobil or ExxonMobil’s equity interest in raw material inputs.

(3)		Refinery capacity is the stream-day capability to process inputs to atmospheric distillation units under normal operating conditions, less the impact of shutdowns for regular repair and maintenance activities, averaged over an extended period of time. These annual averages include partial-year impacts for capacity additions or deletions during the year. Any idle capacity that cannot be made operable in a month or less has been excluded. Capacity volumes include 100 percent of the capacity of refinery facilities managed by ExxonMobil or majority-owned subsidiaries. At facilities of companies owned 50 percent or less, the greater of either that portion of capacity normally available to ExxonMobil or ExxonMobil’s equity interest is included.

REFINING CAPACITY AT YEAR-END 2010⁽¹⁾


							Capacity at 100%
					ExxonMobil												ExxonMobil
					Share		Atmospheric		Catalytic				Residuum				Interest
(thousands of barrels per day)					KBD⁽²⁾		Distillation		Cracking		Hydrocracking		Conversion⁽³⁾		Lubricants⁽⁴⁾		%

United States
Torrance	California		l			150		150		83		21		50		0		100
Joliet	Illinois		l			238		238		94		0		56		0		100
Baton Rouge	Louisiana	n	l			504		504		231		25		116		16		100
Chalmette	Louisiana		l	5		95		189		72		0		29		0		50
Billings	Montana		l			60		60		19		6		10		0		100
Baytown	Texas	n	l			561		561		205		26		90		22		100
Beaumont	Texas	n	l			345		345		113		60		46		10		100
Total United States						1,953		2,047		817		138		397		48

See footnotes on next page.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

REFINING CAPACITY AT YEAR-END 2010⁽¹⁾


							Capacity at 100%
					ExxonMobil												ExxonMobil
					Share		Atmospheric		Catalytic				Residuum				Interest
(thousands of barrels per day)					KBD⁽²⁾		Distillation		Cracking		Hydrocracking		Conversion⁽³⁾		Lubricants⁽⁴⁾		%
Canada
Strathcona	Alberta					189		189		63		0		0		2		69.6
Dartmouth	Nova Scotia			5		83		83		31		0		0		0		69.6
Nanticoke	Ontario			5		113		113		48		0		0		0		69.6
Sarnia	Ontario	n	l			121		121		30		18		26		0		69.6
Total Canada						506		506		172		18		26		2

Europe
Antwerp	Belgium	n	l			307		307		35		0		0		0		100
Fos-sur-Mer	France		l	5		119		119		31		0		0		0		82.9
Port Jerome-Gravenchon	France	n	l			233		233		39		0		0		13		82.9
Karlsruhe	Germany		l	5		78		310		86		0		29		0		25
Augusta	Italy		l	5		198		198		50		0		0		14		100
Trecate	Italy		l	5		174		174		35		0		0		0		74.1
Rotterdam	The Netherlands	n	l			191		191		0		52		41		0		100
Slagen	Norway					116		116		0		0		32		0		100
Fawley	United Kingdom	n	l			329		329		89		0		37		9		100
Total Europe						1,745		1,977		365		52		139		36

Japan
Chiba	Japan		l	5		86		172		33		39		0		0		50
Kawasaki	Japan	n	l			296		296		87		23		0		0		50.1
Sakai	Japan		l	5		139		139		40		0		0		0		50.1
Wakayama	Japan		l	5		160		160		37		0		0		7		50.1
Total Japan						681		767		197		62		0		7

Asia Pacific excluding Japan
Altona	Australia			5		78		78		28		0		0		0		100
Fujian	China	n	l			60		240		38		46		10		0		25
Port Dickson	Malaysia					86		86		0		0		0		0		65
Whangarei	New Zealand					27		134		0		31		0		0		19.2
Jurong/PAC	Singapore	n	l			605		605		0		36		106		38		100
Sriracha	Thailand	n	l			174		174		42		0		0		0		66
Total Asia Pacific excluding Japan						1,030		1,317		108		113		116		38

Middle East
Laffan⁽⁵⁾	Qatar					14		139		0		0		0		0		10
Yanbu	Saudi Arabia					200		400		91		0		46		0		50
Total Middle East						214		539		91		0		46		0

Latin America/Other
Campana	Argentina		l	5		87		87		27		0		24		0		100
Acajutla	El Salvador					22		22		0		0		0		0		65
Martinique	Martinique					2		17		0		0		0		0		14.5
Managua	Nicaragua			5		20		20		0		0		0		0		100
Total Latin America/Other						131		146		27		0		24		0

Total worldwide						6,260		7,299		1,777		383		748		131


n	Integrated refinery and chemical complex

l	Cogeneration capacity

5	Refineries with some chemical production

(1)	Capacity data is based on 100 percent of rated refinery process unit stream-day capacities under normal operating conditions, less the impact of shutdowns for regular repair and maintenance activities, averaged over an extended period of time.

(2)	ExxonMobil share reflects 100 percent of atmospheric distillation capacity in operations of ExxonMobil and majority-owned subsidiaries. For companies owned 50 percent or less, ExxonMobil share is the greater of ExxonMobil’s equity interest or that portion of distillation capacity normally available to ExxonMobil.

(3)	Includes thermal cracking, visbreaking, coking, and hydrorefining processes.

(4)	Lubes capacity based on dewaxed oil production.

(5)	Financial results incorporated into Upstream Qatar business.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

PETROLEUM PRODUCT SALES⁽¹⁾ BY GEOGRAPHIC AREA


(thousands of barrels per day)	2010		2009		2008		2007		2006

United States
Motor gasoline, naphthas		1,445		1,425		1,449		1,601		1,598
Heating oils, kerosene, diesel oils		480		517		501		470		520
Aviation fuels		181		207		224		235		236
Heavy fuels		122		106		108		121		81
Lubricants, specialty, and other petroleum products		283		268		258		290		294
Total United States		2,511		2,523		2,540		2,717		2,729

Canada
Motor gasoline, naphthas		217		199		203		207		204
Heating oils, kerosene, diesel oils		125		119		131		139		143
Aviation fuels		27		23		25		25		24
Heavy fuels		27		27		30		33		32
Lubricants, specialty, and other petroleum products		54		45		55		57		70
Total Canada		450		413		444		461		473

Europe
Motor gasoline, naphthas		423		409		409		414		427
Heating oils, kerosene, diesel oils		707		710		730		723		738
Aviation fuels		116		127		149		177		188
Heavy fuels		179		175		183		220		202
Lubricants, specialty, and other petroleum products		186		204		241		239		258
Total Europe		1,611		1,625		1,712		1,773		1,813

Asia Pacific
Motor gasoline, naphthas		365		379		378		403		409
Heating oils, kerosene, diesel oils		432		455		467		477		493
Aviation fuels		95		116		123		111		106
Heavy fuels		209		234		238		276		288
Lubricants, specialty, and other petroleum products		140		145		153		152		165
Total Asia Pacific		1,241		1,329		1,359		1,419		1,461

Latin America
Motor gasoline, naphthas		80		83		139		151		160
Heating oils, kerosene, diesel oils		113		113		161		173		180
Aviation fuels		29		28		45		48		48
Heavy fuels		34		33		47		48		55
Lubricants, specialty, and other petroleum products		24		22		27		27		26
Total Latin America		280		279		419		447		469

Middle East/Africa
Motor gasoline, naphthas		81		78		76		74		68
Heating oils, kerosene, diesel oils		94		99		106		112		117
Aviation fuels		28		35		41		45		49
Heavy fuels		32		23		30		17		24
Lubricants, specialty, and other petroleum products		86		24		34		34		44
Total Middle East/Africa		321		259		287		282		302

Worldwide
Motor gasoline, naphthas		2,611		2,573		2,654		2,850		2,866
Heating oils, kerosene, diesel oils		1,951		2,013		2,096		2,094		2,191
Aviation fuels		476		536		607		641		651
Heavy fuels		603		598		636		715		682
Lubricants, specialty, and other petroleum products		773		708		768		799		857

Total worldwide		6,414		6,428		6,761		7,099		7,247


(1)		Petroleum product sales include 100 percent of the sales of ExxonMobil and majority-owned subsidiaries, and the ExxonMobil equity interest in sales by companies owned 50 percent or less.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

PETROLEUM PRODUCT SALES⁽¹⁾


(thousands of barrels per day)	2010		2009		2008		2007		2006

Market and Supply Sales⁽¹⁾

Market sales

Motor gasoline, naphthas		1,774		1,795		1,926		2,077		2,133

Heating oils, kerosene, diesel oils		1,252		1,255		1,372		1,448		1,544

Aviation fuels		273		290		365		408		440

Heavy fuels		280		289		329		383		396

Lubricants, specialty, and other petroleum products		253		257		283		297		323

Total market sales		3,832		3,886		4,275		4,613		4,836

Total supply sales		2,582		2,542		2,486		2,486		2,411

Total market and supply sales		6,414		6,428		6,761		7,099		7,247


(1)		Market sales are to retail site dealers, consumers (including government and military), jobbers, and small resellers. Supply sales are to large oil marketers, large unbranded resellers, and other oil companies.

RETAIL SITES


(number of sites at year end)	2010		2009		2008		2007		2006

United States
Owned/leased		1,243		1,921		2,155		2,225		2,375
Distributors/resellers		8,520		8,295		8,296		8,679		8,742
Total United States		9,763		10,216		10,451		10,904		11,117

Canada
Owned/leased		500		518		557		583		613
Distributors/resellers		1,349		1,326		1,314		1,327		1,327
Total Canada		1,849		1,844		1,871		1,910		1,940

Europe
Owned/leased		3,965		4,153		4,131		4,249		4,508
Distributors/resellers		2,584		2,674		2,796		2,843		2,886
Total Europe		6,549		6,827		6,927		7,092		7,394

Asia Pacific
Owned/leased		1,963		2,305		2,416		2,568		2,696
Distributors/resellers		3,631		3,960		4,253		4,844		5,368
Total Asia Pacific		5,594		6,265		6,669		7,412		8,064

Latin America
Owned/leased		567		587		776		1,196		1,246
Distributors/resellers		1,329		1,350		1,372		2,885		3,008
Total Latin America		1,896		1,937		2,148		4,081		4,254

Middle East/Africa
Owned/leased		472		481		481		625		713
Distributors/resellers		155		150		127		362		366
Total Middle East/Africa		627		631		608		987		1,079

Worldwide
Owned/leased		8,710		9,965		10,516		11,446		12,151
Distributors/resellers		17,568		17,755		18,158		20,940		21,697

Total worldwide		26,278		27,720		28,674		32,386		33,848

COMPETITIVE ADVANTAGES

Balanced Portfolio Quality • Our unique mix of commodity and specialty businesses, as well as the strength across the individual businesses in our portfolio, delivers superior performance relative to competition throughout the business cycle.

Disciplined Investing • A highly structured capital management approach ensures that we invest in projects with feedstock, technology, and marketing advantages that can compete in the toughest market environments.

High-Impact Technologies • Proprietary technology expands our access to advantaged feedstock, reduces the cost of our manufacturing processes, and fosters growth of higher-value premium products with unique attributes.

Operational Excellence • We strive for best-in-class performance in areas such as safety, reliability, energy efficiency, and quality through disciplined practices and systems.

Global Integration • Synergies with our Upstream and Downstream deliver benefits through the physical integration of sites, joint feedstock and facilities planning, global competency networks, and sharing of services and best practices. As a result, we capture cost and capital efficiencies while upgrading refining and gas molecules to their highest value.

Chemical

UNIQUE ADVANTAGES OVER COMPETITION

ExxonMobil Chemical’s unique combination of advantaged feedstocks, lower-cost processes, and premium products is unmatched in the industry. Since 2001, we have achieved returns that are more than double that of our competition, including both chemical companies and the chemical operations of integrated oil companies.

Key to this performance is the integration with ExxonMobil’s Upstream and Downstream. This provides a secure source of molecules that we upgrade and sell into growing commodity and specialty markets to achieve the highest value for our shareholders. Our integrated operations also provide scale and synergy advantages, lowering unit costs and increasing capital efficiency.

ExxonMobil’s proprietary technology allows us to optimize feedstock selection and process conditions at our integrated complexes to maximize value. Technology also underpins the ongoing strengthening of our product portfolio and supports the development of new products that provide benefits to our customers. Finally, our technology promotes sustainability by reducing energy usage and environmental impact both for ourselves and our customers.

BUSINESS ENVIRONMENT

In 2010, demand for our chemical products recovered from the economic downturn in 2008 and early 2009. We expect global commodity chemical demand to grow 4 to 5 percent per year over the next decade, about 2 percent above gross domestic product (GDP).

Demand growth is expected to be led by Asia Pacific, particularly China and India. ExxonMobil is well-positioned to supply this demand from our competitive capacity in the Middle East and Asia Pacific, including production at our integrated joint venture in Fujian, China. The major expansion under way at our integrated Singapore complex will increase this advantaged supply position for both commodity and specialty products.

In the major markets outside of Asia Pacific, demand growth is expected to be in line with GDP. We are well-positioned in North America and Europe with highly competitive, world-scale assets.

Our Chemical business is expected to continue to grow and, when leveraged with our unique strengths, is positioned to create substantial value for our shareholders.


CHEMICAL STATISTICAL RECAP	2010		2009		2008		2007		2006

Earnings (millions of dollars)		4,913		2,309		2,957		4,563		4,382

Prime product sales⁽¹⁾ (thousands of tonnes)		25,891		24,825		24,982		27,480		27,350

Average capital employed⁽²⁾ (millions of dollars)		18,680		16,560		14,525		13,430		13,183

Return on average capital employed⁽²⁾ (percent)		26.3		13.9		20.4		34.0		33.2

Capital expenditures (millions of dollars)		2,215		3,148		2,819		1,782		756


(1)		Prime product sales include ExxonMobil’s share of equity-company volumes and finished-product transfers to the Downstream.

(2)		See Frequently Used Terms on pages 98 through 101.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

2010 was a record year for ExxonMobil Chemical Company.
We outpaced competition in both safety and financial performance.

RESULTS & HIGHLIGHTS

Workforce safety performance was best-ever for ExxonMobil Chemical. We continue to lead our competitors in lost-time injury performance.

Earnings were a record $4.9 billion, reflecting the positive impacts of advantaged feedstock, a high degree of integration, and record earnings from our specialty businesses.

Return on average capital employed was 26 percent, averaging 20 percent over the last 10 years, outperforming competition throughout the business cycle.

Prime product sales of 25.9 million tonnes were 4 percent higher than 2009, including an 8-percent increase in specialty sales. Total sales reflect industry demand recovery and the start-up of new capacity at our joint venture in Fujian, China.

Chemical capital expenditures were $2.2 billion, as construction activity peaked on our world-scale project in Singapore. We continued disciplined investment in specialty business growth and high-return efficiency projects.

The Shanghai Technology Center was commissioned. It will support premium product growth in Asia Pacific by delivering innovative customer applications (see page 93).

20 percent
average return
on capital employed
over the last 10 years,
more than double
that of competition

ExxonMobil Chemical expanded our competitive advantage in return on capital employed both at the top and bottom of the last business cycle.


(1) Competitor values are estimated on a consistent basis with ExxonMobil and based on public information. Chemical segments only: Dow Chemical, Chevron (through 2009), BP (through 2004), Royal Dutch Shell.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Focus on Businesses that Capitalize on Core Competencies

Our Chemical business has a unique product portfolio that delivers significant advantages over competition.

Unique Product Portfolio Our product portfolio is a unique combination of commodity and specialty businesses that has been developed primarily through application of proprietary technology rather than via acquisition. Commodities include olefins, polyolefins, and aromatics – the basic building blocks used to make packaging film, automotive parts, and polyester fiber. Specialties include high-performance fluids that are used in water treatment, additives and basestocks for advanced lubricants, and polymers that help tires stay inflated longer.

Portfolio Delivers Advantages We have spent many years developing a portfolio of products that deliver advantages such as higher growth and higher value. Our world-scale commodity chemicals capture upside earnings when industry margins are strong. Our specialty chemicals provide a stable yet growing earnings base, benefiting significantly from the lower-cost structure enabled by feedstock and scale advantages when produced at the same integrated sites as our commodity chemicals.

Our commodity chemicals delivered more than $3 billion in earnings at the top of the cycle and strong results during the weak economic conditions of 2008 and 2009. Our specialty chemicals provide a stable earnings base that grew to a record $1.8 billion in earnings in 2010.

UpClose: Sustainability

ExxonMobil Chemical is committed to the principles of sustainability, which reflect the need to balance economic growth, social development, and environmental concerns.

We reduce material and energy use in our manufacturing operations and minimize our environmental impact.

We also enable more sustainable operations for our customers. Using our proprietary technology, we continue to upgrade our products to make them stronger and easier to process. This allows our customers to use less material and produce lighter-weight products, which reduces not only the energy used for processing and transportation, but also related emissions.

Examples of our products that reduce energy usage include stronger, lighter-weight plastics, advanced polymers that help tires maintain air pressure, and basestocks for advanced lubricants. Reduced energy usage conserves energy resources and reduces emissions, the essence of sustainability.

A recently published, industry-commissioned, and independently validated study concluded that for every unit of carbon dioxide (CO₂) emitted by the chemical industry over the product life cycle, more than two units of CO₂ are saved through the use of these chemical products and technologies. Without products from the chemical industry, global CO₂ emissions would actually be more than 8 percent higher than current levels.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Build Proprietary Technology Positions

Technology is a key enabler of our advantaged growth. We focus on breakthroughs in the use of advantaged feedstocks, lower-cost processes, and premium products.

Advantaged Feedstocks Our proprietary technology enables us to process the broadest range of feedstocks in industry. The combination of our integration, advanced optimization tools, and flexible process designs allows our plants to respond quickly to changes in feedstock quality, availability, and cost. Over the last seven years, we have qualified over 400 new steam-cracking feedstocks around the world, giving us significant capability to minimize raw material costs.

Lower-Cost Manufacturing Processes We rigorously improve our manufacturing cost performance by using advanced processes and catalyst technologies to deliver improved energy efficiency, greater reliability, and increased yields. Our new proprietary butyl technology allows the cryogenic butyl reaction to occur at warmer temperatures than conventional technology, saving energy and capital investment while increasing capacity.

Premium Products Breakthroughs in catalyst and product technologies help deliver new, higher-value products that provide a number of performance advantages. Our proprietary product and application technologies allow us to tailor innovative solutions

to meet our customers’ needs, creating a significant competitive advantage. For example, our metallocene-based products serve a wide range of applications from flexible packaging to consumer products to lubricants and offer superior properties that our customers value (see right).

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Capture Full Benefits of Integration Across ExxonMobil Operations

The guiding principle for our integrated model is to upgrade molecules to the highest value for the shareholder.

The benefits derived from integration are a key differentiating factor that allows ExxonMobil Chemical to outperform competition. Our world-scale, integrated assets have substantial flexibility to process a wide range of feedstocks, and we optimize molecules and product streams among the refinery, chemical steam cracker, and other units. Globally managed support organizations leverage best practices to deliver superior services at a competitive cost. Through our integrated model, we upgrade molecules to their highest value, providing lower-cost raw materials for our businesses.

Consistently Deliver Best-in-Class Performance

Our disciplined approach to improve safety, reliability, energy efficiency, and quality continues to increase the contribution of our assets.

Consistent with our Operations Integrity Management System (OIMS), business practices and systems have been developed and continuously improved over many years to ensure uncompromising integrity of our operations. We use benchmarking along with internal metrics and processes to achieve industry-leading performance.

Our global organization enables rapid, consistent implementation of best practices and new technology while facilitating resource sharing. This approach allows us to provide reliable supply of high-quality products to our customers while providing a competitive advantage through lower costs and higher margins for our businesses.

As a result of this disciplined approach, in 2010 our Chemical business achieved record performance in total workforce safety, environmental compliance, and energy efficiency.

The energy efficiency of our steam crackers is consistently better and has improved at a rate
one-third faster than industry.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Selectively Invest in Advantaged Projects

We manage our capital project portfolio to enhance our access to advantaged feedstocks, deploy lower-cost processes, and grow premium products. Our advantaged projects deliver superior returns across the business cycle and are durable over a wide range of market conditions.

Value through Disciplined Investment We have a healthy pipeline of projects to capture growth while adding value to the Corporation. We continue to invest in the growth of our specialty businesses, as well as develop projects around the world to enhance our feedstock flexibility.

Energy and efficiency projects make up an appreciable portion of our investment. We continue to invest in technology to make further breakthroughs in products and processes to maintain and extend our competitive advantage.

Well-Positioned for Asia Pacific Growth Through 2020, we expect more than 60 percent of global petrochemical demand growth will occur in Asia Pacific, with over one-third in China. We plan to support this growth while adding shareholder value.

Since start-up in the third quarter of 2009, our joint venture in Fujian, China, has sold more than 3 million tonnes of product.

This world-scale, fully integrated petrochemical complex is well-positioned to meet demand in the rapidly growing Chinese market.

In Singapore, construction is well-advanced on one of the largest projects ever executed by ExxonMobil. The project will more than double the site’s steam-cracking capacity, provide unparalleled feedstock flexibility, and be energy efficient. The significant increase in commodity and specialty product capacity will enable us to capture both growth and value. When the project is complete, Singapore will be the site of ExxonMobil’s largest integrated complex in the world.

Our recently commissioned Shanghai Technology Center will support our business in meeting the growing premium product demand in Asia Pacific.

Detailed studies are progressing for a major expansion of our joint venture in Saudi Arabia to develop specialty products for the auto industry.

We are progressing other opportunities to develop advantaged projects that would be well-positioned to supply the demand growth in Asia Pacific.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Chemical Operating Statistics

LARGE/INTEGRATED PRODUCTION COMPLEX CAPACITY⁽¹⁾⁽²⁾

(millions of tonnes per year)

Ethylene

Polyethylene

Polypropylene

Paraxylene

Additional Products

North America

Baton Rouge, Louisiana

1.0

1.3

0.4

–

P B E A F O

Baytown, Texas

2.2

–

0.8

0.6

P B F

Beaumont, Texas

0.8

1.0

–

0.3

P S

Mont Belvieu, Texas

–

1.0

–

Sarnia, Ontario

0.3

0.5

–

P F O

Europe

Antwerp, Belgium

0.5

0.4

–

P F O

Fawley, United Kingdom

–

B F O

Fife, United Kingdom

0.4

–

Meerhout, Belgium

–

0.5

–

Notre-Dame-de-
Gravenchon, France

0.4

0.3

–

P B E A O S Z

Rotterdam, the Netherlands

–

0.7

Middle East

Al Jubail, Saudi Arabia

0.6

–

Yanbu, Saudi Arabia

1.0

0.7

0.2

–

Asia Pacific

Fujian, China

0.2

0.1

0.2

Kawasaki, Japan

0.5

0.1

–

P B A F

Singapore

0.9

0.6

0.4

0.9

P F O Z

Sriracha, Thailand

–

0.5

All other

–

0.6

Total worldwide

8.8

7.3

2.2

3.8

P Propylene B Butyl E Specialty Elastomers A Adhesive Polymers F Fluids O Oxo Alcohols S Synthetics Z Petroleum Additives


(1)		Based on size or breadth of product slate.

(2)		Capacity reflects 100 percent for operations of ExxonMobil and majority-owned subsidiaries. For companies owned 50 percent or less, capacity is ExxonMobil’s interest.

OTHER MANUFACTURING LOCATIONS⁽¹⁾


Location	Product



North America
Bayway, New Jersey	5	l
Belleville, Ontario		u
Chalmette, Louisiana	n
Dartmouth, Nova Scotia		l
Edison, New Jersey		l
LaGrange, Georgia		u
Pensacola, Florida	5
Plaquemine, Louisiana	5
Shawnee, Oklahoma		u

Latin America
Campana, Argentina	n	l
Managua, Nicaragua		l
Paulinia, Brazil		l
Rio de Janeiro, Brazil		l


Location	Product



Europe
Augusta, Italy	n
Berre, France		l
Brindisi, Italy		u
Cologne, Germany	5	l
Fos-sur-Mer, France	n
Geleen, the Netherlands	5
Karlsruhe, Germany	n
Kerkrade, the Netherlands		u
Newport, United Kingdom	5
Trecate, Italy		l
Vado Ligure, Italy		l
Virton, Belgium		u


Location	Product



Asia Pacific
Adelaide, Australia⁽²⁾		l
Altona, Australia	n
Gumi, South Korea			u
Jinshan, China		5
Chiba, Japan	n
Kashima, Japan		5
Nasu, Japan			u
Panyu, China		l
Sakai, Japan	n	l
Wakayama, Japan	n


(1)		Includes joint-venture plants.

(2)		Facility mothballed.

n Olefins/Aromatics 5 Polymers l Other Chemicals u Films

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

VOLUMES


Includes ExxonMobil’s share of equity companies	2010		2009		2008		2007		2006

Worldwide Production Volumes (thousands of tonnes)

Ethylene		7,973		7,381		7,540		8,155		7,878

Polyethylene		6,506		6,120		6,088		6,693		6,275

Polypropylene		1,945		1,864		1,897		1,897		1,815

Paraxylene		2,808		2,758		2,472		2,995		3,038



Prime Product Sales Volumes⁽¹⁾ by Region (thousands of tonnes)

Americas⁽²⁾		10,826		10,665		10,628		12,034		11,907

Europe/Middle East/Africa		6,654		6,433		6,635		7,463		7,497

Asia Pacific		8,411		7,727		7,719		7,983		7,946


Total worldwide		25,891		24,825		24,982		27,480		27,350



Prime Product Sales Volumes⁽¹⁾ by Business (thousands of tonnes)

Less-cyclical specialty businesses		5,586		5,183		5,618		6,237		6,228

Olefins/polyolefins/aromatics/other		20,305		19,642		19,364		21,243		21,122



Total		25,891		24,825		24,982		27,480		27,350


(1)		Prime product sales include ExxonMobil’s share of equity-company volumes and finished product transfers to the Downstream.

(2)		Includes North America and Latin America.


2010 Prime Product Sales Volumes		2010 Average Capital Employed
(percent, thousands of tonnes)		(percent, millions of dollars)

Strong and Unique Portfolio Mix


	Worldwide Rank		Worldwide Rank
Businesses	Based on Market Position		Based on Market Position

Commodities		Specialties

Benzene	#2	Butyl Polymers	#1

Paraxylene	#2	Fluids	#1

Olefins	#2	Plasticizers/Oxo Alcohols	#1

Polyethylene	#2	Synthetics	#1

Polypropylene	#4	Oriented Polypropylene Films	#1

		Adhesive Polymers	#1

		Specialty Elastomers	#1

		Petroleum Additives	#2

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Frequently Used Terms

Listed below are definitions of several of ExxonMobil’s key business and financial performance measures and other terms. These definitions are provided to facilitate understanding of the terms and their calculation. In the case of financial measures that we believe constitute “non-GAAP financial measures” under Securities and Exchange Commission Regulation G, we provide a reconciliation to the most comparable Generally Accepted Accounting Principles (GAAP) measure and other information required by that rule.

EARNINGS EXCLUDING SPECIAL ITEMS

In addition to reporting U.S. GAAP defined net income, ExxonMobil also presents a measure of earnings that excludes earnings from special items quantified and described in our quarterly and annual earnings press releases. Earnings excluding special items is a non-GAAP financial measure, and is included to facilitate comparisons of base business performance across periods. A reconciliation to net income attributable to ExxonMobil is shown on page 16. We also refer to earnings excluding special items as normalized earnings. Earnings per share amounts use the same average common shares outstanding as used for the calculation of earnings per common share and earnings per common share – assuming dilution.

OPERATING COSTS

Operating costs are the combined total of production, manufacturing, selling, general, administrative, exploration, depreciation, and depletion expenses from the Consolidated Statement of Income and ExxonMobil’s share of similar costs for equity companies. Operating costs are the costs during the period to produce, manufacture, and otherwise prepare the company’s products for sale – including energy costs, staffing, maintenance, and other costs to explore for and produce oil and gas, and operate refining and chemical plants. Distribution and marketing expenses are also included. Operating costs exclude the cost of raw materials, taxes, and interest expense. These expenses are on a before-tax basis. While ExxonMobil’s management is responsible for all revenue and expense elements of net income, operating costs, as defined below, represent the expenses most directly under management’s control. Information regarding these costs is, therefore, useful for investors and ExxonMobil management in evaluating management’s performance.



(millions of dollars)	2010		2009		2008		2007		2006


Reconciliation of Operating Costs

From ExxonMobil’s Consolidated Statement of Income

Total costs and other deductions		330,262		275,809		393,962		333,073		309,182

Less:

Crude oil and product purchases		197,959		152,806		249,454		199,498		182,546

Interest expense		259		548		673		400		654

Sales-based taxes		28,547		25,936		34,508		31,728		30,381

Other taxes and duties		36,118		34,819		41,719		40,953		39,203

Subtotal		67,379		61,700		67,608		60,494		56,398

ExxonMobil’s share of equity-company expenses		9,049		6,670		7,204		5,619		4,947


Total operating costs		76,428		68,370		74,812		66,113		61,345



(millions of dollars)	2010		2009		2008		2007		2006

Components of Operating Costs

From ExxonMobil’s Consolidated Statement of Income

Production and manufacturing expenses		35,792		33,027		37,905		31,885		29,528

Selling, general, and administrative expenses		14,683		14,735		15,873		14,890		14,273

Depreciation and depletion		14,760		11,917		12,379		12,250		11,416

Exploration expenses, including dry holes		2,144		2,021		1,451		1,469		1,181

Subtotal		67,379		61,700		67,608		60,494		56,398

ExxonMobil’s share of equity-company expenses		9,049		6,670		7,204		5,619		4,947


Total operating costs		76,428		68,370		74,812		66,113		61,345

TOTAL SHAREHOLDER RETURN

Shareholder return measures the change in value of an investment in stock over a specified period of time, assuming dividend reinvestment. We calculate shareholder return over a particular measurement period by: dividing (1) the sum of (a) the cumulative value of dividends received during the measurement period, assuming reinvestment, plus (b) the difference between the stock price at the end and at the beginning of the measurement period; by (2) the stock price at the beginning of the measurement period. For this purpose, we assume dividends are reinvested in stock at market prices at approximately the same time actual dividends are paid. Shareholder return is usually quoted on an annualized basis.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

CAPITAL AND EXPLORATION EXPENDITURES (Capex)

Capital and exploration expenditures are the combined total of additions at cost to property, plant and equipment and exploration expenses on a before-tax basis from the Summary Statement of Income. ExxonMobil’s Capex includes its share of similar costs for equity companies. Capex excludes depreciation on the cost of exploration support equipment and facilities recorded to property, plant and equipment when acquired. While ExxonMobil’s management is responsible for all investments and elements of net income, particular focus is placed on managing the controllable aspects of this group of expenditures.

CAPITAL EMPLOYED

Capital employed is a measure of net investment. When viewed from the perspective of how the capital is used by the businesses, it includes ExxonMobil’s net share of property, plant and equipment and other assets less liabilities, excluding both short-term and long-term debt. When viewed from the perspective of the sources of capital employed in total for the Corporation, it includes ExxonMobil’s share of total debt and equity. Both of these views include ExxonMobil’s share of amounts applicable to equity companies, which the Corporation believes should be included to provide a more comprehensive measure of capital employed.



(millions of dollars)	2010			2009			2008			2007			2006


Business Uses: Asset and Liability Perspective

Total assets		302,510			233,323			228,052			242,082			219,015

Less liabilities and noncontrolling interests share of assets and liabilities

Total current liabilities excluding notes and loans payable		(59,846	)		(49,585	)		(46,700	)		(55,929	)		(47,115	)

Total long-term liabilities excluding long-term debt		(74,971	)		(58,741	)		(54,404	)		(50,543	)		(45,905	)

Noncontrolling interests share of assets and liabilities		(6,532	)		(5,642	)		(6,044	)		(5,332	)		(4,948	)

Add ExxonMobil share of debt-financed equity-company net assets		4,875			5,043			4,798			3,386			2,808

Total capital employed		166,036			124,398			125,702			133,664			123,855


Total Corporate Sources: Debt and Equity Perspective

Notes and loans payable		2,787			2,476			2,400			2,383			1,702

Long-term debt		12,227			7,129			7,025			7,183			6,645

ExxonMobil share of equity		146,839			110,569			112,965			121,762			113,844

Less noncontrolling interests share of total debt		(692	)		(819	)		(1,486	)		(1,050	)		(1,144	)

Add ExxonMobil share of equity-company debt		4,875			5,043			4,798			3,386			2,808

Total capital employed		166,036			124,398			125,702			133,664			123,855

RETURN ON AVERAGE CAPITAL EMPLOYED (ROCE)

Return on average capital employed is a performance measure ratio. From the perspective of the business segments, ROCE is annual business segment earnings divided by average business segment capital employed (average of beginning- and end-of-year amounts). These segment earnings include ExxonMobil’s share of segment earnings of equity companies, consistent with our capital employed definition, and exclude the cost of financing. The Corporation’s total ROCE is net income attributable to ExxonMobil excluding the after-tax cost of financing, divided by total corporate average capital employed. The Corporation has consistently applied its ROCE definition for many years and views it as the best measure of historical capital productivity in our capital-intensive, long-term industry, both to evaluate management’s performance and to demonstrate to shareholders that capital has been used wisely over the long term. Additional measures, which are more cash flow-based, are used to make investment decisions.



(millions of dollars)	2010			2009			2008			2007			2006


Return on Average Capital Employed

Net income attributable to ExxonMobil		30,460			19,280			45,220			40,610			39,500

Financing costs (after tax)

Gross third-party debt		(803	)		(303	)		(343	)		(339	)		(264	)

ExxonMobil share of equity companies		(333	)		(285	)		(325	)		(204	)		(156	)

All other financing costs – net		35			(483	)		1,485			268			499

Total financing costs		(1,101	)		(1,071	)		817			(275	)		79

Earnings excluding financing costs		31,561			20,351			44,403			40,885			39,421

Average capital employed		145,217			125,050			129,683			128,760			122,573

Return on average capital employed – corporate total		21.7%			16.3%			34.2%			31.8%			32.2%

100

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

ENTITLEMENT VOLUME EFFECTS

Production Sharing Contract Net Interest Reductions • Production Sharing Contract (PSC) net interest reductions are contractual reductions in ExxonMobil’s share of production volumes covered by PSCs. These reductions typically occur when cumulative investment returns or production volumes achieve thresholds as specified in the PSCs. Once a net interest reduction has occurred, it typically will not be reversed by subsequent events, such as lower crude oil prices.

Price and Spend Impacts on Volumes • Price and spend impacts on volumes are fluctuations in ExxonMobil’s share of production volumes caused by changes in oil and gas prices or spending levels from one period to another. For example, at higher prices fewer barrels are required for ExxonMobil to recover its costs. According to the terms of contractual arrangements or government royalty regimes, price or spending variability can increase or decrease royalty burdens and/or volumes attributable to ExxonMobil. These effects generally vary from period to period with field spending patterns or market prices for crude oil or natural gas.

HEAVY OIL AND OIL SANDS

Heavy oil, for the purpose of this report, includes heavy oil, extra heavy oil, and bitumen, as defined by the World Petroleum Congress in 1987 based on American Petroleum Institute (API) gravity and viscosity at reservoir conditions. Heavy oil has an API gravity between 10 and 22.3 degrees. The API gravity of extra heavy oil and bitumen is less than 10 degrees. Extra heavy oil has a viscosity less than 10 thousand centipoise, whereas the viscosity of bitumen is greater than 10 thousand centipoise. The term “oil sands” is used to indicate heavy oil (generally bitumen) that is recovered in a mining operation.

EXPLORATION RESOURCE ADDITION COST

Exploration resource addition cost per oil-equivalent barrel is a performance measure that is calculated using the Exploration portion of Upstream capital and exploration expenditures divided by exploration resource additions (in oil-equivalent barrels). ExxonMobil refers to new discoveries, and the non-proved portion of discovered resources that were acquired, as exploration resource additions. Exploration resource additions include quantities of oil and gas that are not yet classified as proved reserves, but which ExxonMobil believes will likely be moved into the proved reserves category and produced in the future. The impact of the XTO Energy Inc. merger transaction is excluded from this calculation.



	2010		2009		2008		2007		2006


Exploration portion of Upstream capital and exploration expenditures (millions of dollars)		4,121		3,718		2,871		1,909		2,044

Exploration resource additions (millions of oil-equivalent barrels)		4,725		2,860		2,230		1,995		2,855

Exploration resource addition cost per oil-equivalent barrel (dollars)		0.87		1.30		1.29		0.96		0.72

PROVED RESERVES

Proved reserves in this publication for 2009 and later years are based on current SEC definitions, but for prior years, the referenced proved reserve volumes are determined on bases that differ from SEC definitions in effect at the time. Specifically, for years prior to 2009 included in our five-year average replacement ratio, reserves are determined using the SEC pricing basis but including oil sands and our pro-rata share of equity company reserves for all periods. Prior to 2009, oil sands and equity company reserves were not included in proved oil and gas reserves as defined by the SEC. In addition, prior to 2009, the SEC defined price as the market price on December 31; beginning in 2009, the SEC changed the definition to the average of the market prices on the first day of each calendar month during the year. For years prior to 2009 included in our 17 straight years of at least 100-percent replacement, reserves are determined using the price and cost assumptions we use in managing the business, not the historical prices used in SEC definitions. Reserves determined on ExxonMobil’s pricing basis also include oil sands and equity company reserves for all periods.

RESOURCES, RESOURCE BASE, AND RECOVERABLE RESOURCES

Resources, resource base, recoverable resources, recoverable oil, recoverable hydrocarbons, and similar terms used in this report are the total remaining estimated quantities of oil and gas that are expected to be ultimately recoverable. ExxonMobil refers to new discoveries and acquisitions of discovered resources as resource additions. The resource base includes quantities of oil and gas that are not yet classified as proved reserves, but which ExxonMobil believes will likely be moved into the proved reserves category and produced in the future. The term “resource base” is not intended to correspond to SEC definitions such as “probable” or “possible” reserves.

PROVED RESERVES REPLACEMENT RATIO

The reserves replacement ratio is calculated for a specified period utilizing the applicable proved oil-equivalent reserves additions divided by oil-equivalent production. See “Proved Reserves” above.

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

PROVED RESERVES REPLACEMENT COSTS

Proved reserves replacement costs per oil-equivalent barrel is a performance measure ratio. Proved reserves replacement costs per barrel are costs incurred in property acquisition and exploration, plus costs incurred in development activities, divided by proved oil-equivalent reserves additions, excluding sales. Unless otherwise specified, ExxonMobil reports these costs based on proved reserves using SEC historical prices and costs. See “Proved Reserves” on previous page.



(millions of dollars)	2010		2009		2008		2007		2006


Costs incurred
Property acquisition costs		45,461		1,285		663		194		597
Exploration costs		3,055		3,111		2,272		1,762		1,685
Development costs		23,210		17,130		14,633		11,570		12,103

Total costs incurred		71,726		21,526		17,568		13,526		14,385



(millions of barrels)	2010		2009		2008		2007		2006


Proved oil-equivalent reserves additions
Revisions		505		383		690		1,405		687
Improved recovery		5		15		7		36		29
Extensions/discoveries		516		1,091		1,423		248		679
Purchases		2,510		1		–		2		755

Total oil-equivalent reserves additions		3,536		1,490		2,120		1,691		2,150
Proved reserves replacement costs (dollars per barrel)		20.28		14.45		8.29		8.00		6.69

CASH FLOW FROM OPERATIONS AND ASSET SALES

Cash flow from operations and asset sales is the sum of the net cash provided by operating activities and proceeds from sales of subsidiaries, investments, and property, plant and equipment from the Summary Statement of Cash Flows. This cash flow is the total sources of cash from both operating the Corporation’s assets and from the divesting of assets. The Corporation employs a long-standing and regular disciplined review process to ensure that all assets are contributing to the Corporation’s strategic objectives. Assets are divested when they are no longer meeting these objectives or are worth considerably more to others. Because of the regular nature of this activity, we believe it is useful for investors to consider sales proceeds together with cash provided by operating activities when evaluating cash available for investment in the business and financing activities, including shareholder distributions.



(millions of dollars)	2010		2009		2008		2007		2006


Net cash provided by operating activities		48,413		28,438		59,725		52,002		49,286
Sales of subsidiaries, investments and property, plant and equipment		3,261		1,545		5,985		4,204		3,080

Cash flow from operations and asset sales		51,674		29,983		65,710		56,206		52,366

DISTRIBUTIONS TO SHAREHOLDERS

The Corporation distributes cash to shareholders in the form of both dividends and share purchases. Shares are purchased both to reduce shares outstanding and to offset shares issued in conjunction with company benefit plans and programs. For purposes of calculating distributions to shareholders, the Corporation only includes the cost of those shares purchased to reduce shares outstanding.



(millions of dollars)	2010		2009		2008		2007		2006


Dividends paid to ExxonMobil shareholders		8,498		8,023		8,058		7,621		7,628
Cost of shares purchased to reduce shares outstanding		11,200		18,000		32,000		28,000		25,000

Distributions to ExxonMobil shareholders		19,698		26,023		40,058		35,621		32,628

Memo: Gross cost of shares purchased to offset shares issued under benefit plans and programs		1,893		1,703		3,734		3,822		4,558

101

102

EXXON MOBIL CORPORATION • 2010 FINANCIAL & OPERATING REVIEW

Index


Acreage			28, 29, 64
Africa			29, 33, 37, 52-55
Asia Pacific 29, 35, 36, 37, 56-60, 88, 90, 95
Australia/Oceania			29, 33, 35, 37, 60-61

Balance Sheet			21
Business strategies			2-3, 24, 72, 88

Canada 29, 30, 31, 33, 35, 37, 45-47
Capital and exploration expenditures			18-19, 99
Capital employed			17, 81, 99
Cash flow			15, 23, 101
Cash Flow Statement			23
Chemical capacity			96
Chemical products			93, 97
Chemical projects			95
Chemical results			90-91
Chemical volumes			97

Depreciation and depletion			20, 70-71
Dividend and shareholder distributions			14
Downstream results			74-75

Earnings			5, 15, 16, 70-71
Earnings, oil and gas			70-71
Earnings per barrel			27, 32
Energy management			11, 32, 79
Energy Outlook			6-9
Entitlement volumes			33, 100
Europe 29, 35, 37, 48-51, 81
Exploration captures			29
Exploration resource addition cost			27, 30, 31, 100

Financial highlights			4, 5
Frequently Used Terms			98-101
Fuels Marketing 74, 76, 77, 78, 80, 81

Heavy oil and oil sands			31, 39, 46, 100

Income Statement			22
Integration 3, 25, 73, 80, 89, 90, 94

Key financial ratios			4

LNG 9, 26, 35, 36, 43, 48, 49, 50, 52, 56-57, 59, 60-61
Lubricants and Specialties 74, 76, 77, 78, 79, 81

Marine well containment			43
Middle East 35, 36, 37, 56-57, 58-59, 90
Molecule Management			12, 73, 77


Natural gas and power markets			35

Operating costs 20, 22, 78, 94, 98
Operations Integrity Management System 10, 32, 76, 94

Petroleum product sales			15, 74, 86
Price and spend impacts			100
Project execution			3, 34
Production sharing contract 33, 54, 59, 60, 100
Production volumes 26, 33, 62, 63, 100
Property, plant and equipment			20, 99, 101

Qatar 26, 33, 35, 36, 37, 43, 56-57

Refinery utilization			84
Refining and Supply			74, 75, 76-83
Refining capacity			84-85
Reserves and resources 26, 27, 28, 30, 31, 66-69
Reserves replacement costs			69, 101
Reserves replacement ratio 26, 31, 67, 68, 69, 100
Retail sites			76, 81, 87
Return on average capital employed 5, 17, 27, 75, 91, 99
Russia/Caspian 31, 35, 36, 37, 58-59

Safety, Security, Health & Environment			10-11
Share purchases			14, 101
Shareholder return			5, 14, 98
South America			47

Technology 12, 38-41, 82-83, 93

Unconventional gas 35, 43, 44, 48, 50
United States 9, 26, 29, 33, 35, 36, 37, 42-45, 81, 83
Upstream development project summary			36-37
Upstream production profile			33, 37
Upstream results			26-27

Wells, net drilled			64

XTO Energy Inc. 5, 26, 29, 30, 31, 33, 35, 42, 100

Data Tables
Corporate Financial Tables
Capital and Exploration Expenditures			18-19
Capital Employed/ROCE			17
Financial Statements			21-23
Functional Earnings			16

Business Tables
Upstream			62-71
Downstream			84-87
Chemical			96-97

Exxon Mobil Corporation has numerous affiliates, many with names that include ExxonMobil, Exxon, Mobil, and Esso. For convenience and simplicity, those terms and terms such as Corporation, company, our, we, and its are sometimes used as abbreviated references to specific affiliates or affiliate groups. Abbreviated references describing global or regional operational organizations, and global or regional business lines are also sometimes used for convenience and simplicity. Similarly, ExxonMobil has business relationships with thousands of customers, suppliers, governments, and others. For convenience and simplicity, words such as venture, joint venture, partnership, co-venturer, and partner are used to indicate business and other relationships involving common activities and interests, and those words may not indicate precise legal relationships.

The following are trademarks, service marks, or proprietary process names of Exxon Mobil Corporation or one of its affiliates: ExxonMobil, Esso, Exxon, Mobil, Mobil 1, Mobil DTE Excel, Mobil SHC, Mobil SHC Pegasus, Controlled Freeze Zone, Fast Drill, Vybs, R³M, SCANfining, SpectraSyn Elite, Enable, Exceed, Vistamaxx, Where Industrial Productivity Begins, and Taking on the World’s Toughest Energy Challenges.

The following third-party trademarks or service marks, referenced in the text of the report are owned by the entities indicated: Vodafone (Vodafone Group Plc), McLaren (McLaren Racing Limited), Mercedes (Daimler AG), Loss Prevention System (Loss Prevention Systems, Inc.).

General Information

Corporate Headquarters
Exxon Mobil Corporation
5959 Las Colinas Boulevard
Irving, TX 75039-2298

Additional copies may be
obtained by writing or phoning:
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Fax: 972-444-1505

Shareholder Relations
Exxon Mobil Corporation
P.O. Box 140369
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Market Information
The New York Stock Exchange is the principal exchange
on which Exxon Mobil Corporation common stock
(symbol XOM) is traded.

Annual Meeting
The 2011 Annual Meeting of Shareholders will be held at
9:00 a.m. Central Time on Wednesday, May 25, 2011, at:

The Morton H. Meyerson Symphony Center
2301 Flora Street
Dallas, Texas 75201

The meeting will be audiocast live on the Internet.
Instructions for listening to this audiocast will be
available on the Internet at exxonmobil.com
approximately one week prior to the event.

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