View Filing Data

^[1]

$ 370,125

$ 301,500

$ 459,579

10,677

7,143

11,081

^[2]

2,419

1,943

6,699

383,221

310,586

477,359

Costs and other deductions

197,959

152,806

249,454

35,792

33,027

37,905

14,683

14,735

15,873

14,760

11,917

12,379

2,144

2,021

1,451

259

548

673

^[1]

28,547

25,936

34,508

36,118

34,819

41,719

330,262

275,809

393,962

52,959

34,777

83,397

21,561

15,119

36,530

Net income attributable to noncontrolling interests

31,398

19,658

46,867

938

378

1,647

Earnings per common share (dollars)

$ 30,460

$ 19,280

$ 45,220

$ 6.24

$ 3.99

$ 8.7

Earnings per common share - assuming dilution (dollars)

$ 6.22

$ 3.98

$ 8.66

[1]	Sales and other operating revenue includes sales-based taxes of $28,547 million for 2010, $25,936 million for 2009 and $34,508 million for 2008.
[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.

CONSOLIDATED STATEMENT OF INCOME (Parenthetical) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2010

Dec. 31, 2009

Dec. 31, 2008

CONSOLIDATED STATEMENT OF INCOME

Sales and other operating revenue, sales-based taxes

^[1]

$ 28,547

$ 25,936

$ 34,508

Other income, gain from the sale of a non-U.S. investment

Other income, foreign exchange loss related to the sale of a non-U.S. investment

$ 143

[1]	Sales and other operating revenue includes sales-based taxes of $28,547 million for 2010, $25,936 million for 2009 and $34,508 million for 2008.

CONSOLIDATED BALANCE SHEET - USD ($) $ in Millions	12 Months Ended
CONSOLIDATED BALANCE SHEET - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009
Current assets
Cash and cash equivalents	$ 7,825	$ 10,693
Cash and cash equivalents - restricted	628
Marketable securities	2	169
Notes and accounts receivable, less estimated doubtful amounts	32,284	27,645
Inventories
Crude oil, products and merchandise	9,852	8,718
Materials and supplies	3,124	2,835
Other current assets	5,269	5,175
Total current assets	58,984	55,235
Investments, advances and long-term receivables	35,338	31,665
Property, plant and equipment, at cost, less accumulated depreciation and depletion	199,548	139,116
Other assets, including intangibles, net	8,640	7,307
Total assets	302,510	233,323
Current liabilities
Notes and loans payable	2,787	2,476
Accounts payable and accrued liabilities	50,034	41,275
Income taxes payable	9,812	8,310
Total current liabilities	62,633	52,061
Long-term debt	12,227	7,129
Postretirement benefits reserves	19,367	17,942
Deferred income tax liabilities	35,150	23,148
Other long-term obligations	20,454	17,651
Total liabilities	$ 149,831	$ 117,931
Commitments and contingencies
Equity
Common stock without par value (9,000 million shares authorized, 8,019 million shares issued)	$ 9,371	$ 5,503
Earnings reinvested	298,899	276,937
Accumulated other comprehensive income
Cumulative foreign exchange translation adjustment	5,011	4,402
Postretirement benefits reserves adjustment	(9,889)	(9,863)
Unrealized gain/(loss) on cash flow hedges	55
Common stock held in treasury (3,040 million shares in 2010 and 3,292 million shares in 2009)	(156,608)	(166,410)
ExxonMobil share of equity	146,839	110,569
Noncontrolling interests	5,840	4,823
Total equity	152,679	115,392
Total liabilities and equity	$ 302,510	$ 233,323

CONSOLIDATED BALANCE SHEET (Parenthetical) - $ / shares shares in Millions	Dec. 31, 2010	Dec. 31, 2009
Statement [Line Items]
Common stock, without par value	$ 0	$ 0
Common stock, shares authorized	9,000	9,000
Common stock, shares issued	8,019	8,019
Common stock held in treasury, shares	3,040	3,292

CONSOLIDATED STATEMENT OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Cash flows from operating activities
Net income including noncontrolling interests	$ 31,398	$ 19,658	$ 46,867
Adjustments for noncash transactions
Depreciation and depletion	14,760	11,917	12,379
Deferred income tax charges/(credits)	(1,135)		1,399
Postretirement benefits expense in excess of/(less than) net payments	1,700	(1,722)	57
Other long-term obligation provisions in excess of/(less than) payments	160	731	(63)
Dividends received greater than/(less than) equity in current earnings of equity companies	(596)	(483)	921
Changes in operational working capital, excluding cash and debt
Reduction/(increase) - Notes and accounts receivable	(5,863)	(3,170)	8,641
- Inventories	(1,148)	459	(1,285)
- Other current assets	913	132	(509)
Increase/(reduction) - Accounts and other payables	9,943	1,420	(5,415)
Net (gain) on asset sales	(1,401)	(488)	(3,757)
All other items - net	(318)	(16)	490
Net cash provided by operating activities	48,413	28,438	59,725
Cash flows from investing activities
Additions to property, plant and equipment	(26,871)	(22,491)	(19,318)
Sales of subsidiaries, investments and property, plant and equipment	3,261	1,545	5,985
Decrease/(increase) in restricted cash and cash equivalents	(628)
Additional investments and advances	(1,239)	(2,752)	(2,495)
Collection of advances	1,133	724	574
Additions to marketable securities	(15)	(16)	(2,113)
Sales of marketable securities	155	571	1,868
Net cash used in investing activities	(24,204)	(22,419)	(15,499)
Cash flows from financing activities
Additions to long-term debt	1,143	225	79
Reductions in long-term debt	(6,224)	(68)	(192)
Additions to short-term debt	598	1,336	1,067
Reductions in short-term debt	(2,436)	(1,575)	(1,624)
Additions/(reductions) in debt with three months or less maturity	709	(71)	143
Cash dividends to ExxonMobil shareholders	(8,948)	(8,023)	(8,058)
Cash dividends to noncontrolling interests	(281)	(280)	(375)
Changes in noncontrolling interests	(7)	(113)	(419)
Tax benefits related to stock-based awards	122	237	333
Common stock acquired	(13,093)	(19,703)	(35,734)
Common stock sold	1,043	752	753
Net cash used in financing activities	(26,924)	(27,283)	(44,027)
Effects of exchange rate changes on cash	(153)	520	(2,743)
Increase/(decrease) in cash and cash equivalents	(2,868)	(20,744)	(2,544)
Cash and cash equivalents at beginning of year	10,693	31,437	33,981
Cash and cash equivalents at end of year	$ 7,825	$ 10,693	$ 31,437

CONSOLIDATED STATEMENT OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2010	Jun. 25, 2010
CONSOLIDATED STATEMENT OF CASH FLOWS
Value of XTO Energy Inc. equity acquired	$ 24,659	$ 24,659

CONSOLIDATED STATEMENT OF CHANGES IN EQUITY - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Balance	$ 115,392	$ 117,523	$ 126,044
Amortization of stock-based awards	751	685	618
Tax benefits related to stock-based awards	280	140	315
Other	(673)	(636)	(552)
Net income for the year	31,398	19,658	46,867
Dividends - common shares	(8,779)	(8,303)	(8,433)
Foreign exchange translation adjustment	1,034	3,629	(7,298)
Adjustment for foreign exchange translation loss included in net income	25		155
Postretirement benefits reserves adjustment (note 16)	(1,161)	(340)	(6,077)
Amortization of postretirement benefits reserves adjustment included in net periodic benefit costs (note 16)	1,040	1,461	759
Change in fair value of cash flow hedges	184
Realized (gain)/ loss from settled cash flow hedges included in net income	(129)
Acquisitions, at cost	(13,908)	(19,830)	(36,409)
Issued for XTO merger	24,659
Dispositions	1,756	1,405	1,534
Balance	152,679	115,392	117,523
Common Stock [Member]
Statement [Line Items]
Balance	$ 5,503	$ 5,314	$ 4,933
Balance (in shares)	8,019	8,019	8,019
Amortization of stock-based awards	$ 751	$ 685	$ 618
Tax benefits related to stock-based awards	280	140	315
Other	(683)	(636)	(552)
Issued for XTO merger	3,520
Balance	$ 9,371	$ 5,503	$ 5,314
Balance (in shares)	8,019	8,019	8,019
Earnings Reinvested [Member]
Statement [Line Items]
Balance	$ 276,937	$ 265,680	$ 228,518
Net income for the year	30,460	19,280	45,220
Dividends - common shares	(8,498)	(8,023)	(8,058)
Balance	298,899	276,937	265,680
Accumulated Other Comprehensive Income [Member]
Statement [Line Items]
Balance	(5,461)	(9,931)	1,989
Foreign exchange translation adjustment	584	3,256	(6,964)
Adjustment for foreign exchange translation loss included in net income	25		138
Postretirement benefits reserves adjustment (note 16)	(1,014)	(196)	(5,853)
Amortization of postretirement benefits reserves adjustment included in net periodic benefit costs (note 16)	988	1,410	759
Change in fair value of cash flow hedges	184
Realized (gain)/ loss from settled cash flow hedges included in net income	(129)
Balance	(4,823)	(5,461)	(9,931)
Common Stock Held in Treasury [Member]
Statement [Line Items]
Balance	$ (166,410)	$ (148,098)	$ (113,678)
Balance (in shares)	(3,292)	(3,043)	(2,637)
Acquisitions, at cost	$ (13,903)	$ (19,703)	$ (35,734)
Issued for XTO merger	21,139
Dispositions	$ 1,756	$ 1,391	$ 1,314
Acquisitions (in shares)	(199)	(277)	(434)
Issued for XTO merger (in shares)	416
Other dispositions (in shares)	35	28	28
Balance	$ (156,608)	$ (166,410)	$ (148,098)
Balance (in shares)	(3,040)	(3,292)	(3,043)
Exxon Mobil Share of Equity [Member]
Statement [Line Items]
Balance	$ 110,569	$ 112,965	$ 121,762
Amortization of stock-based awards	751	685	618
Tax benefits related to stock-based awards	280	140	315
Other	(683)	(636)	(552)
Net income for the year	30,460	19,280	45,220
Dividends - common shares	(8,498)	(8,023)	(8,058)
Foreign exchange translation adjustment	584	3,256	(6,964)
Adjustment for foreign exchange translation loss included in net income	25		138
Postretirement benefits reserves adjustment (note 16)	(1,014)	(196)	(5,853)
Amortization of postretirement benefits reserves adjustment included in net periodic benefit costs (note 16)	988	1,410	759
Change in fair value of cash flow hedges	184
Realized (gain)/ loss from settled cash flow hedges included in net income	(129)
Acquisitions, at cost	(13,093)	(19,703)	(35,734)
Issued for XTO merger	24,659
Dispositions	1,756	1,391	1,314
Balance	146,839	110,569	112,965
Noncontrolling Interests [Member]
Statement [Line Items]
Balance	4,823	4,558	4,282
Other	10
Net income for the year	938	378	1,647
Dividends - common shares	(281)	(280)	(375)
Foreign exchange translation adjustment	450	373	(334)
Adjustment for foreign exchange translation loss included in net income			17
Postretirement benefits reserves adjustment (note 16)	(147)	(144)	(224)
Amortization of postretirement benefits reserves adjustment included in net periodic benefit costs (note 16)	52	51
Acquisitions, at cost	(5)	(127)	(675)
Dispositions		14	220
Balance	$ 5,840	$ 4,823	$ 4,558
Outstanding [Member]
Statement [Line Items]
Balance (in shares)	4,727	4,976	5,382
Acquisitions (in shares)	(199)	(277)	(434)
Issued for XTO merger (in shares)	416
Other dispositions (in shares)	35	28	28
Balance (in shares)	4,979	4,727	4,976

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
Net income including noncontrolling interests	$ 31,398	$ 19,658	$ 46,867
Other comprehensive income (net of income taxes)
Foreign exchange translation adjustment	1,034	3,629	(7,298)
Adjustment for foreign exchange translation loss included in net income	25		155
Postretirement benefits reserves adjustment (excluding amortization)	(1,161)	(340)	(6,077)
Amortization of postretirement benefits reserves adjustment included in net periodic benefit costs	1,040	1,461	759
Change in fair value of cash flow hedges	184
Realized (gain)/ loss from settled cash flow hedges included in net income	(129)
Comprehensive income including noncontrolling interests	32,391	24,408	34,406
Comprehensive income attributable to noncontrolling interests	1,293	658	1,106
Comprehensive income attributable to ExxonMobil	$ 31,098	$ 23,750	$ 33,300

Summary of Accounting Policies	12 Months Ended
Summary of Accounting Policies	Dec. 31, 2010
Statement [Line Items]
Summary of Accounting Policies	1. Summary of Accounting Policies Principles of Consolidation. The Consolidated Financial Statements include the accounts of those subsidiaries owned directly or indirectly with more than 50 percent of the voting rights held by the Corporation and for which other shareholders do not possess the right to participate in significant management decisions. They also include the Corporation's share of the undivided interest in certain upstream assets and liabilities. Amounts representing the Corporation's percentage interest in the underlying net assets of other subsidiaries and less-than-majority-owned companies in which a significant ownership percentage interest is held are included in "Investments, advances and long-term receivables"; the Corporation's share of the net income of these companies is included in the Consolidated Statement of Income caption "Income from equity affiliates." The Corporation's share of the cumulative foreign exchange translation adjustment for equity method investments is reported in the Consolidated Statement of Changes in Equity. Evidence of loss in value that might indicate impairment of investments in companies accounted for on the equity method is assessed to determine if such evidence represents a loss in value of the Corporation's investment that is other than temporary. Examples of key indicators include a history of operating losses, a negative earnings and cash flow outlook, significant downward revisions to oil and gas reserves, and the financial condition and prospects for the investee's business segment or geographic region. If evidence of an other than temporary loss in fair value below carrying amount is determined, an impairment is recognized. In the absence of market prices for the investment, discounted cash flows are used to assess fair value. Revenue Recognition. The Corporation generally sells crude oil, natural gas and petroleum and chemical products under short-term agreements at prevailing market prices. In some cases (e.g., natural gas), products may be sold under long-term agreements, with periodic price adjustments. In all cases, revenues are recognized when the products are delivered, which occurs when the customer has taken title and has assumed the risks and rewards of ownership, prices are fixed or determinable and collectibility is reasonably assured. Revenues from the production of natural gas properties in which the Corporation has an interest with other producers are recognized on the basis of the Corporation's net working interest. Differences between actual production and net working interest volumes are not significant. Purchases and sales of inventory with the same counterparty that are entered into in contemplation of one another are combined and recorded as exchanges measured at the book value of the item sold. Sales-Based Taxes. The Corporation reports sales, excise and value-added taxes on sales transactions on a gross basis in the Consolidated Statement of Income (included in both revenues and costs). This gross reporting basis is footnoted on the Consolidated Statement of Income. Derivative Instruments. The Corporation makes limited use of derivative instruments. The Corporation does not engage in speculative derivative activities or derivative trading activities, nor does it use derivatives with leveraged features. When the Corporation does enter into derivative transactions, it is to offset exposures associated with interest rates, foreign currency exchange rates and hydrocarbon prices that arise from existing assets, liabilities and forecasted transactions. For derivatives designated as cash flow hedges, the Corporation's activity is intended to manage the price risk posed by physical transactions. The Corporation records all derivatives on the balance sheet at fair value. The change in fair value of derivatives designated as fair value hedges is recognized in earnings, offset by the change in fair value of the hedged item. The change in fair value of derivatives designated as cash flow hedges is recorded in other comprehensive income and recognized in earnings when the hedged transaction is recognized in earnings. The change in fair value of derivatives not designated as hedging instruments is recognized in earnings. Any ineffectiveness between the derivative and the hedged item is recorded in earnings. Hedge effectiveness is reviewed at least quarterly and is generally based on the most recent relevant correlation between the derivative and the item hedged. Hedge ineffectiveness is calculated based on the difference between the change in fair value of the derivative and change in cash flow or fair value of the items hedged. If it is determined that a derivative is no longer highly effective, hedge accounting is then discontinued and the change in fair value since inception that is on the balance sheet either as other comprehensive income for cash flow hedges, or the underlying hedged item for fair value hedges, is recorded in earnings. Fair Value. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 or 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market. Inventories. Crude oil, products and merchandise inventories are carried at the lower of current market value or cost (generally determined under the last-in, first-out method – LIFO). Inventory costs include expenditures and other charges (including depreciation) directly and indirectly incurred in bringing the inventory to its existing condition and location. Selling expenses and general and administrative expenses are reported as period costs and excluded from inventory cost. Inventories of materials and supplies are valued at cost or less. Property, Plant and Equipment. Depreciation, depletion and amortization, based on cost less estimated salvage value of the asset, are primarily determined under either the unit-of-production method or the straight-line method, which is based on estimated asset service life taking obsolescence into consideration. Maintenance and repairs, including planned major maintenance, are expensed as incurred. Major renewals and improvements are capitalized and the assets replaced are retired. Interest costs incurred to finance expenditures during the construction phase of multiyear projects are capitalized as part of the historical cost of acquiring the constructed assets. The project construction phase commences with the development of the detailed engineering design and ends when the constructed assets are ready for their intended use. Capitalized interest costs are included in property, plant and equipment and are depreciated over the service life of the related assets. The Corporation uses the "successful efforts" method to account for its exploration and production activities. Under this method, costs are accumulated on a field-by-field basis with certain exploratory expenditures and exploratory dry holes being expensed as incurred. Costs of productive wells and development dry holes are capitalized and amortized on the unit-of-production method. The Corporation carries as an asset exploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and where the Corporation is making sufficient progress assessing the reserves and the economic and operating viability of the project. Exploratory well costs not meeting these criteria are charged to expense. Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves. Significant unproved properties are assessed for impairment individually and valuation allowances against the capitalized costs are recorded based on the estimated economic chance of success and the length of time that the Corporation expects to hold the properties. Properties that are not individually significant are aggregated by groups and amortized based on development risk and average holding period. The valuation allowances are reviewed at least annually. Other exploratory expenditures, including geophysical costs, other dry hole costs and annual lease rentals, are expensed as incurred. Unit-of-production depreciation is applied to property, plant and equipment, including capitalized exploratory drilling and development costs, associated with productive depletable extractive properties in the Upstream segment. Unit-of-production rates are based on the amount of proved developed reserves of oil, gas and other minerals that are estimated to be recoverable from existing facilities using current operating methods. Under the unit-of-production method, oil and gas volumes are considered produced once they have been measured through meters at custody transfer or sales transaction points at the outlet valve on the lease or field storage tank. Production costs are expensed as incurred. Production involves lifting the oil and gas to the surface and gathering, treating, field processing and field storage of the oil and gas. The production function normally terminates at the outlet valve on the lease or field production storage tank. Production costs are those incurred to operate and maintain the Corporation's wells and related equipment and facilities. They become part of the cost of oil and gas produced. These costs, sometimes referred to as lifting costs, include such items as labor costs to operate the wells and related equipment; repair and maintenance costs on the wells and equipment; materials, supplies and energy costs required to operate the wells and related equipment; and administrative expenses related to the production activity. Gains on sales of proved and unproved properties are only recognized when there is no uncertainty about the recovery of costs applicable to any interest retained or where there is no substantial obligation for future performance by the Corporation. Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value. Proved oil and gas properties held and used by the Corporation are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recoverable. Assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. The Corporation estimates the future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. Cash flows used in impairment evaluations are developed using annually updated corporate plan investment evaluation assumptions for crude oil commodity prices and foreign currency exchange rates. Annual volumes are based on individual field production profiles, which are also updated annually. Prices for natural gas and other products are based on corporate plan assumptions developed annually by major region and also for investment evaluation purposes. Cash flow estimates for impairment testing exclude derivative instruments. Impairment analyses are generally based on proved reserves. Where probable reserves exist, an appropriately risk-adjusted amount of these reserves may be included in the impairment evaluation. Impairments are measured by the amount the carrying value exceeds the fair value. Goodwill. Goodwill is the excess of the consideration transferred over the value of net assets recognized and represents the future economic benefits arising from other assets acquired that could not be individually identified and separately recognized. Goodwill is evaluated for impairment on at least an annual basis. Asset Retirement Obligations and Environmental Liabilities. The Corporation incurs retirement obligations for certain assets at the time they are installed. The fair values of these obligations are recorded as liabilities on a discounted basis. The costs associated with these liabilities are capitalized as part of the related assets and depreciated. Over time, the liabilities are accreted for the change in their present value. Liabilities for environmental costs are recorded when it is probable that obligations have been incurred and the amounts can be reasonably estimated. These liabilities are not reduced by possible recoveries from third parties and projected cash expenditures are not discounted. Foreign Currency Translation. The Corporation selects the functional reporting currency for its international subsidiaries based on the currency of the primary economic environment in which each subsidiary operates. Downstream and Chemical operations primarily use the local currency. However, the U.S. dollar is used in countries with a history of high inflation (primarily in Latin America) and Singapore, which predominantly sells into the U.S. dollar export market. Upstream operations which are relatively self-contained and integrated within a particular country, such as Canada, the United Kingdom, Norway and continental Europe, use the local currency. Some Upstream operations, primarily in Asia and Africa, use the U.S. dollar because they predominantly sell crude and natural gas production into U.S. dollar-denominated markets. For all operations, gains or losses from remeasuring foreign currency transactions into the functional currency are included in income. Stock-Based Payments. The Corporation awards stock-based compensation to employees in the form of restricted stock and restricted stock units. Compensation expense is measured by the market price of the restricted shares at the date of grant and is recognized in the income statement over the requisite service period of each award. See note 14, Incentive Program, for further details.

Accounting Changes	12 Months Ended
Accounting Changes	Dec. 31, 2010
Statement [Line Items]
Accounting Changes	2. Accounting Changes Variable-Interest Entities. Effective January 1, 2010, ExxonMobil adopted the authoritative guidance for variable-interest entities (VIEs). The guidance requires the enterprise to qualitatively assess if it is the primary beneficiary of the VIE and, if so, the VIE must be consolidated. The adoption of the guidance did not have a material impact on the Corporation's financial statements.

Miscellaneous Financial Information

12 Months Ended

Dec. 31, 2010

Miscellaneous Financial Information

3. Miscellaneous Financial Information

Research and development costs totaled $1,012 million in 2010, $1,050 million in 2009 and $847 million in 2008.

Net income included before-tax aggregate foreign exchange transaction losses of $251 million, and gains of $54 million and $54 million in 2010, 2009 and 2008, respectively.

In 2010, 2009 and 2008, net income included gains of $317 million, $207 million and $341 million, respectively, attributable to the combined effects of LIFO inventory accumulations and draw-downs. The aggregate replacement cost of inventories was estimated to exceed their LIFO carrying values by $21.3 billion and $17.1 billion at December 31, 2010, and 2009, respectively.

Crude oil, products and merchandise as of year-end 2010 and 2009 consist of the following:


	2010		2009
	(billions of dollars)
Petroleum products	$	3.5	$	3.2
Crude oil		3.8		3.2
Chemical products		2.1		2.0
Gas/other		0.5		0.3

Total	$	9.9	$	8.7

The December 31, 2010, total cash and cash equivalents balance of $8,453 million includes $628 million of restricted funds.

Cash Flow Information

12 Months Ended

Dec. 31, 2010

Cash Flow Information

4. Cash Flow Information

The Consolidated Statement of Cash Flows provides information about changes in cash and cash equivalents. Highly liquid investments with maturities of three months or less when acquired are classified as cash equivalents.

The "Net (gain) on asset sales" in net cash provided by operating activities on the Consolidated Statement of Cash Flows includes before-tax gains from the sale of some Upstream Gulf of Mexico and other producing properties, the sale of U.S. service stations and other Downstream assets and investments and the formation of a Chemical joint venture in 2010; from the sale of Downstream assets and investments and producing properties in the Upstream in 2009; and from the sale of a natural gas transportation business in Germany and other producing properties in the Upstream and Downstream assets and investments in 2008. These gains are reported in "Other income" on the Consolidated Statement of Income.


	2010		2009		2008
	(millions of dollars)
Cash payments for interest	$	703	$	820	$	650

Cash payments for income taxes	$	18,941	$	15,427	$	33,941

Additional Working Capital Information

12 Months Ended

Dec. 31, 2010

Additional Working Capital Information

5. Additional Working Capital Information


	Dec. 31 2010		Dec. 31 2009
	(millions of dollars)
Notes and accounts receivable
Trade, less reserves of $152 million and $198 million	$	25,439	$	22,186
Other, less reserves of $34 million and $31 million		6,845		5,459

Total	$	32,284	$	27,645


Notes and loans payable
Bank loans	$	532	$	1,043
Commercial paper		1,346		201
Long-term debt due within one year		345		348
Other		564		884

Total	$	2,787	$	2,476


Accounts payable and accrued liabilities
Trade payables	$	30,780	$	24,236
Payables to equity companies		5,450		4,979
Accrued taxes other than income taxes		6,778		5,921
Other		7,026		6,139

Total	$	50,034	$	41,275

On December 31, 2010, unused credit lines for short-term financing totaled approximately $5.6 billion. Of this total, $2.8 billion support commercial paper programs under terms negotiated when drawn. The weighted-average interest rate on short-term borrowings outstanding at December 31, 2010, and 2009, was 1.2 percent and 3.6 percent, respectively.

Equity Company Information

12 Months Ended

Dec. 31, 2010

Equity Company Information

6. Equity Company Information

The summarized financial information below includes amounts related to certain less-than-majority-owned companies and majority-owned subsidiaries where minority shareholders possess the right to participate in significant management decisions (see note 1). These companies are primarily engaged in crude production, natural gas marketing and refining operations in North America; natural gas production, natural gas distribution and downstream operations in Europe; crude production in Kazakhstan; and liquefied natural gas (LNG) operations in Qatar. Also included are several power generation, refining, petrochemical manufacturing and chemical ventures. The Corporation's ownership in these ventures is in the form of shares in corporate joint ventures as well as interests in partnerships. The share of total equity company revenues from sales to ExxonMobil consolidated companies was 18 percent, 19 percent and 21 percent in the years 2010, 2009 and 2008, respectively.


	2010				2009				2008
Equity Company Financial Summary	Total		ExxonMobil Share		Total		ExxonMobil Share		Total		ExxonMobil Share
	(millions of dollars)
Total revenues	$	153,020	$	48,355	$	112,153	$	36,570	$	148,477	$	49,999

Income before income taxes	$	48,075	$	14,735	$	28,472	$	9,632	$	42,588	$	15,082
Income taxes		13,962		4,058		7,775		2,489		12,020		4,001

Income from equity affiliates	$	34,113	$	10,677	$	20,697	$	7,143	$	30,568	$	11,081


Current assets	$	48,573	$	15,860	$	37,376	$	12,843	$	29,358	$	9,920
Long-term assets		90,646		29,805		88,153		27,983		87,442		28,339

Total assets	$	139,219	$	45,665	$	125,529	$	40,826	$	116,800	$	38,259

Current liabilities	$	33,160	$	10,260	$	24,854	$	8,085	$	26,221	$	8,707
Long-term liabilities		59,596		17,976		57,384		16,999		50,895		15,094

Net assets	$	46,463	$	17,429	$	43,291	$	15,742	$	39,684	$	14,458

A list of significant equity companies as of December 31, 2010, together with the Corporation's percentage ownership interest, is detailed below:


	Percentage Ownership Interest
Upstream
Aera Energy LLC		48
BEB Erdgas und Erdoel GmbH		50
Cameroon Oil Transportation Company S.A.		41
Castle Peak Power Company Limited		60
Golden Pass LNG Terminal LLC		18
Nederlandse Aardolie Maatschappij B.V.		50
Qatar Liquefied Gas Company Limited		10
Qatar Liquefied Gas Company Limited 2		24
Ras Laffan Liquefied Natural Gas Company Limited		25
Ras Laffan Liquefied Natural Gas Company Limited II		31
Ras Laffan Liquefied Natural Gas Company Limited (3)		30
South Hook LNG Terminal Company Limited		24
Tengizchevroil, LLP		25
Terminale GNL Adriatico S.r.l.		69

Downstream
Chalmette Refining, LLC		50
Fujian Refining & Petrochemical Co. Ltd.		25
Saudi Aramco Mobil Refinery Company Ltd.		50

Chemical
Al-Jubail Petrochemical Company		50
Infineum Holdings B.V.		50
Saudi Yanbu Petrochemical Co.		50
Toray Tonen Specialty Separator Godo Kaisha		50

Investments, Advances and Long-Term Receivables

12 Months Ended

Dec. 31, 2010

Investments, Advances and Long-Term Receivables

7. Investments, Advances and Long-Term Receivables


	Dec. 31 2010		Dec. 31 2009
	(millions of dollars)
Companies carried at equity in underlying assets
Investments	$	17,429	$	15,742
Advances		9,286		8,669

	$	26,715	$	24,411
Companies carried at cost or less and stock investments carried at fair value		1,557		1,577

	$	28,272	$	25,988
Long-term receivables and miscellaneous investments at cost or less, net of reserves of $292 million and $368 million		7,066		5,677

Total	$	35,338	$	31,665

Property, Plant and Equipment and Asset Retirement Obligations

12 Months Ended

Dec. 31, 2010

Property, Plant and Equipment and Asset Retirement Obligations

8. Property, Plant and Equipment and Asset Retirement Obligations


	Dec. 31, 2010				Dec. 31, 2009
Property, Plant and Equipment	Cost		Net		Cost		Net
			(millions of dollars)
Upstream	$	264,136	$	148,152	$	198,036	$	88,319
Downstream		68,652		30,095		68,092		30,499
Chemical		29,524		14,255		28,464		13,511
Other		11,626		7,046		11,314		6,787

Total	$	373,938	$	199,548	$	305,906	$	139,116

In the Upstream segment, depreciation is generally on a unit-of production basis, so depreciable life will vary by field. In the Downstream segment, investments in refinery and lubes basestock manufacturing facilities are generally depreciated on a straight-line basis over a 25-year life and service station buildings and fixed improvements over a 20-year life. In the Chemical segment, investments in process equipment are generally depreciated on a straight-line basis over a 20-year life.

Accumulated depreciation and depletion totaled $174,390 million at the end of 2010 and $166,790 million at the end of 2009. Interest capitalized in 2010, 2009 and 2008 was $532 million, $425 million and $510 million, respectively.

Asset Retirement Obligations

The Corporation incurs retirement obligations for its upstream assets. The fair values of these obligations are recorded as liabilities on a discounted basis, which is typically at the time the assets are installed. The Corporation uses estimates, assumptions and judgments regarding such factors as the existence of a legal obligation for an ARO; technical assessments of the assets; estimated amounts and timing of settlements; the credit-adjusted risk-free rate to be used; and inflation rates. AROs incurred in the current period were Level 3 (unobservable inputs) fair value measurements. The costs associated with these liabilities are capitalized as part of the related assets and depreciated as the reserves are produced. Over time, the liabilities are accreted for the change in their present value. Asset retirement obligations for downstream and chemical facilities generally become firm at the time the facilities are permanently shut down and dismantled. These obligations may include the costs of asset disposal and additional soil remediation. However, these sites have indeterminate lives based on plans for continued operations and as such, the fair value of the conditional legal obligations cannot be measured, since it is impossible to estimate the future settlement dates of such obligations.

The following table summarizes the activity in the liability for asset retirement obligations:


	2010			2009
	(millions of dollars)
Beginning balance	$	8,473		$	5,352
Accretion expense and other provisions		563			372
Reduction due to property sales		(183	)		(18	)
Payments made		(638	)		(448	)
Liabilities incurred		1,094			156
Foreign currency translation		(45	)		535
Revisions		350			2,524

Ending balance	$	9,614		$	8,473

Accounting for Suspended Exploratory Well Costs

12 Months Ended

Dec. 31, 2010

Accounting for Suspended Exploratory Well Costs

9. Accounting for Suspended Exploratory Well Costs

The Corporation continues capitalization of exploratory well costs beyond one year after the well is completed if (a) the well found a sufficient quantity of reserves to justify its completion as a producing well and (b) sufficient progress is being made in assessing the reserves and the economic and operating viability of the project.

The following two tables provide details of the changes in the balance of suspended exploratory well costs as well as an aging summary of those costs.

Change in capitalized suspended exploratory well costs:


	2010			2009			2008
	(millions of dollars)
Balance beginning at January 1	$	2,005		$	1,585		$	1,291
Additions pending the determination of proved reserves		1,103			624			448
Charged to expense		(104	)		(51	)		—
Reclassifications to wells, facilities and equipment based on the determination of proved reserves		(136	)		(200	)		(101	)
Other		25			47			(53	)

Ending balance	$	2,893		$	2,005		$	1,585

Ending balance attributed to equity companies included above	$	—		$	9		$	10

Period end capitalized suspended exploratory well costs:


	2010		2009		2008
	(millions of dollars)
Capitalized for a period of one year or less	$	1,103	$	624	$	448
Capitalized for a period of between one and five years		1,294		924		636
Capitalized for a period of between five and ten years		278		220		225
Capitalized for a period of greater than ten years		218		237		276

Capitalized for a period greater than one year – subtotal	$	1,790	$	1,381	$	1,137

Total	$	2,893	$	2,005	$	1,585

Exploration activity often involves drilling multiple wells, over a number of years, to fully evaluate a project The table below provides a numerical breakdown of the number of projects with suspended exploratory well costs which had their first capitalized well drilled in the preceding 12 months and those that have had exploratory well costs capitalized for a period greater than 12 months.


	2010		2009		2008
Number of projects with first capitalized well drilled in the preceding 12 months		9		18		12
Number of projects that have exploratory well costs capitalized for a period of greater than 12 months		59		57		50

Total		68		75		62

Of the 59 projects that have exploratory well costs capitalized for a period greater than 12 months as of December 31, 2010, 25 projects have drilling in the preceding 12 months or exploratory activity planned in the next two years, while the remaining 34 projects are those with completed exploratory activity progressing toward development. The table below provides additional detail for those 34 projects, which total $692 million.


Country/Project	Dec 31, 2010		Years Wells Drilled		Comment
(millions of dollars)
Angola
- Perpetua-Zina-Acacia	$	15		2008 - 2009	Oil field near Pazflor development, awaiting capacity in existing/planned infrastructure.
Australia
- East Pilchard		10		2001	Gas field near Kipper/Tuna development, awaiting capacity in existing/planned infrastructure.
Indonesia
- Natuna		118		1981 - 1983	Development activity under way, while continuing discussions with the government on contract terms pursuant to recently executed Heads of Agreement.
Kazakhstan
- Kairan		53		2004 - 2007	Declarations involving field commerciality filed with Kazakhstan government in 2008; progressing commercialization and field development studies.
Nigeria
- Bolia		15		2002 - 2006	Evaluating development plan, while continuing discussions with the government regarding regional hub strategy.
- Bonga North		34		2004 - 2009	Pursuing alignment with operator and government regarding development plan.
- Bosi		79		2002 - 2006	Development activity under way while continuing discussions with the government regarding development plan.
- Other (5 projects)		16		2001 - 2002	Pursuing development of several additional offshore satellite discoveries which will tie back to existing/planned production facilities.
Norway
- Gamma		20		2008 - 2009	Evaluating development plan for tieback to existing production facilities.
- H-North		15		2007	Discovery near existing facilities in Fram area; evaluating development options.
- Lavrans		23		1995 - 1999	Development awaiting capacity in existing Kristin production facility; evaluating development concepts for phased ullage scenarios.
- Noatun		19		2008	Evaluating development plan for tieback to existing production facilities.
- Nyk High		20		2008	Evaluating field development alternatives.
- Other (8 projects)		34		1992 - 2009	Evaluating development plans, including potential for tieback to existing production facilities.
Papua New Guinea
- Juha		28		2007	Working on development plans to tie into planned LNG facilities.
United Kingdom
- Fram		55		2009	Progressing development and commercialization plans.
- Other (3 projects)		21		2001 - 2008	Projects primarily awaiting capacity in existing or planned infrastructure.
United States
- Julia Unit		78		2007 - 2008	Julia Unit owners are progressing development plans and have agreed to share funding on facilities at the Chevron-operated Jack-Saint Malo platform. Suspension of Production for the Julia Unit is under review by the Bureau of Ocean Energy Management, Regulation and Enforcement.
- Tip Top		31		2009	Evaluating development concept and requisite facility upgrades.
Other
- Various (2 projects)		8		1979 - 1995	Projects primarily awaiting capacity in existing or planned infrastructure.
Total 2010 (34 projects)	$	692

Leased Facilities

12 Months Ended

Dec. 31, 2010

Leased Facilities

10. Leased Facilities

At December 31, 2010, the Corporation and its consolidated subsidiaries held noncancelable operating charters and leases covering drilling equipment, tankers, service stations and other properties with minimum undiscounted lease commitments totaling $7,776 million as indicated in the table. Estimated related rental income from noncancelable subleases is $62 million.


	Lease Payments Under Minimum Commitments		Related Sublease Rental Income
	(millions of dollars)
2011	$	2,095	$	8
2012		1,570		8
2013		1,061		7
2014		731		6
2015		581		6
2016 and beyond		1,738		27

Total	$	7,776	$	62

Net rental cost under both cancelable and noncancelable operating leases incurred during 2010, 2009 and 2008 were as follows:


	2010		2009		2008
	(millions of dollars)
Rental cost	$	3,762	$	4,426	$	4,115
Less sublease rental income		90		98		123

Net rental cost	$	3,672	$	4,328	$	3,992

Earnings Per Share

12 Months Ended

Dec. 31, 2010

Earnings Per Share

11. Earnings Per Share


	2010		2009		2008
Earnings per common share

Net income attributable to ExxonMobil (millions of dollars)	$	30,460	$	19,280	$	45,220

Weighted average number of common shares outstanding (millions of shares)		4,885		4,832		5,194

Earnings per common share (dollars)	$	6.24	$	3.99	$	8.70

Earnings per common share – assuming dilution

Net income attributable to ExxonMobil (millions of dollars)	$	30,460	$	19,280	$	45,220

Weighted average number of common shares outstanding (millions of shares)		4,885		4,832		5,194
Effect of employee stock-based awards		12		16		27

Weighted average number of common shares outstanding – assuming dilution		4,897		4,848		5,221


Earnings per common share – assuming dilution (dollars)	$	6.22	$	3.98	$	8.66

Dividends paid per common share (dollars)	$	1.74	$	1.66	$	1.55

Financial Instruments and Derivatives	12 Months Ended
Financial Instruments and Derivatives	Dec. 31, 2010
Statement [Line Items]
Financial Instruments and Derivatives	12. Financial Instruments and Derivatives Financial Instruments. The fair value of financial instruments is determined by reference to observable market data and other valuation techniques as appropriate. The only category of financial instruments where the difference between fair value and recorded book value is notable is long-term debt. The estimated fair value of total long-term debt, including capitalized lease obligations, was $12.8 billion and $7.7 billion at December 31, 2010, and 2009, respectively, as compared to recorded book values of $12.2 billion and $7.1 billion at December 31, 2010, and 2009, respectively. The fair value hierarchy for long-term debt is primarily Level 1 (quoted prices for identical assets in active markets). Derivative Instruments. The Corporation's size, strong capital structure, geographic diversity and the complementary nature of the Upstream, Downstream and Chemical businesses reduce the Corporation's enterprise-wide risk from changes in interest rates, currency rates and commodity prices. As a result, the Corporation makes limited use of derivatives to mitigate the impact of such changes. The Corporation does not engage in speculative derivative activities or derivative trading activities nor does it use derivatives with leveraged features. When the Corporation does enter into derivative transactions, it is to offset exposures associated with interest rates, foreign currency exchange rates and hydrocarbon prices that arise from existing assets, liabilities and forecasted transactions. For derivatives designated as cash flow hedges, the Corporation's activity is intended to manage the price risk posed by physical transactions. The estimated fair value of derivative instruments outstanding and recorded on the balance sheet was a net asset of $172 million at year-end 2010 and a net liability of $5 million at year-end 2009. This is the amount that the Corporation would have received from, or paid to, third parties if these derivatives had been settled in the open market. Assets and liabilities associated with derivatives are predominantly recorded either in "Other current assets" or "Accounts payable and accrued liabilities." The year-end 2010 net asset balance includes the Corporation's outstanding cash flow hedge position, acquired as a result of the XTO merger, of $219 million. As the current cash flow hedge positions settle, these programs will be discontinued. The Corporation's fair value measurement of its derivative instruments uses primarily Level 2 inputs (derivatives that are determined by either market prices on an active market for similar assets or by prices quoted by a broker or other market-corroborated prices). The Corporation recognized a before-tax gain or (loss) related to derivative instruments of $221 million, $(73) million and $154 million during 2010, 2009 and 2008, respectively. Income statement effects associated with derivatives are recorded either in "Sales and other operating revenue" or "Crude oil and product purchases." Of the amount stated above for 2010, cash flow hedges resulted in a before-tax gain of $218 million. The ineffective portion of derivatives designated as hedges is de minimis. The principal natural gas futures contracts and swap agreements acquired as part of the XTO merger that are in place as of December 31, 2010, will expire by the end of 2011. The associated volume of natural gas is 250 mcfd at a weighted average NYMEX price of $7.02 per thousand cubic feet. These derivative contracts qualify for cash flow hedge accounting. The Corporation will receive the cash flow related to these derivative contracts at the price indicated above. However, the amount of the income statement gain or loss realized from these contracts will be limited to the change in fair value of the derivative instruments from the acquisition date of XTO. The Corporation believes that there are no material market or credit risks to the Corporation's financial position, results of operations or liquidity as a result of the derivative activities described above. The fair value of derivatives outstanding at year-end 2010 and the gain recognized during the year are immaterial.

Long-Term Debt

12 Months Ended

Dec. 31, 2010

Long-Term Debt

13. Long-term Debt

At December 31, 2010, long-term debt consisted of $11,610 million due in U.S. dollars and $617 million representing the U.S. dollar equivalent at year-end exchange rates of amounts payable in foreign currencies. These amounts exclude that portion of long-term debt, totaling $345 million, which matures within one year and is included in current liabilities. The amounts of long-term debt maturing, together with sinking fund payments required, in each of the four years after December 31, 2011, in millions of dollars, are: 2012 – $3,222, 2013 – $1,019, 2014 – $622 and 2015 – $601. At December 31, 2010, the Corporation's unused long-term credit lines were not material.

Summarized long-term debt at year-end 2010 and 2009 are shown in the table below:


	2010		2009
	(millions of dollars)
SeaRiver Maritime Financial Holdings, Inc. (1)
Guaranteed debt securities due 2011 (2)	$	—	$	13
Guaranteed deferred interest debentures due 2012 – Face value net of unamortized discount plus accrued interest		2,389		2,144
XTO Energy Inc. (premium in millions of dollars)
7.500% senior note due 2012 includes premium of $15		199		—
5.900% senior note due 2012 includes premium of $16		233		—
6.250% senior note due 2013 includes premium of $18		193		—
4.625% senior note due 2013 includes premium of $9		149		—
5.750% senior note due 2013 includes premium of $37		359		—
4.900% senior note due 2014 includes premium of $19		267		—
5.000% senior note due 2015 includes premium of $13		142		—
5.300% senior note due 2015 includes premium of $28		262		—
5.650% senior note due 2016 includes premium of $27		227		—
6.250% senior note due 2017 includes premium of $80		534		—
5.500% senior note due 2018 includes premium of $49		420		—
6.500% senior note due 2018 includes premium of $86		524		—
6.100% senior note due 2036 includes premium of $29		204		—
6.750% senior note due 2037 includes premium of $69		329		—
6.375% senior note due 2038 includes premium of $46		258		—

Mobil Services (Bahamas) Ltd.
Variable note due 2035 (3)		972		972
Variable note due 2034 (4)		311		311

Mobil Producing Nigeria Unlimited (5)
Variable notes due 2012-2017		415		621

Esso (Thailand) Public Company Ltd. (6)
Variable notes due 2012-2017		522		165

Mobil Corporation
8.625% debentures due 2021		248		248

Industrial revenue bonds due 2012-2040 (7)		2,247		1,685
Other U.S. dollar obligations (8)		454		536
Other foreign currency obligations		65		66
Capitalized lease obligations (9)		304		368

Total long-term debt	$	12,227	$	7,129

(1)

Additional information is provided for this subsidiary on the following pages.

(2)

Average effective interest rate of 1.6% in 2009.

(3)

Average effective interest rate of 0.3% in 2010 and 0.3% in 2009.

(4)

Average effective interest rate of 0.4% in 2010 and 0.9% in 2009.

(5)

Average effective interest rate of 4.6% in 2010 and 5.4% in 2009.

(6)

Average effective interest rate of 1.7% in 2010 and 2.2% in 2009.

(7)

Average effective interest rate of 0.2% in 2010 and 0.2% in 2009.

(8)

Average effective interest rate of 4.7% in 2010 and 5.0% in 2009.

(9)

Average imputed interest rate of 8.1% in 2010 and 8.8% in 2009.

Exxon Mobil Corporation has fully and unconditionally guaranteed the deferred interest debentures due 2012 ($2,389 million long-term debt at December 31, 2010) and the debt securities due 2011 ($13 million short-term) of SeaRiver Maritime Financial Holdings, Inc.

SeaRiver Maritime Financial Holdings, Inc. is a 100-percent-owned subsidiary of Exxon Mobil Corporation.

The following condensed consolidating financial information is provided for Exxon Mobil Corporation, as guarantor, and for SeaRiver Maritime Financial Holdings, Inc., as issuer, as an alternative to providing separate financial statements for the issuer. The accounts of Exxon Mobil Corporation and SeaRiver Maritime Financial Holdings, Inc. are presented utilizing the equity method of accounting for investments in subsidiaries.


	Exxon Mobil Corporation Parent Guarantor		SeaRiver Maritime Financial Holdings, Inc.			All Other Subsidiaries		Consolidating and Eliminating Adjustments			Consolidated
	(millions of dollars)
Condensed consolidated statement of income for 12 months ended December 31, 2010
Revenues and other income
Sales and other operating revenue, including sales-based taxes	$	15,382	$	—		$	354,743	$	—		$	370,125
Income from equity affiliates		28,401		(2	)		10,589		(28,311	)		10,677
Other income		790		—			1,629		—			2,419
Intercompany revenue		39,433		4			332,483		(371,920	)		—

Total revenues and other income		84,006		2			699,444		(400,231	)		383,221

Costs and other deductions
Crude oil and product purchases		40,788		—			518,961		(361,790	)		197,959
Production and manufacturing expenses		7,627		—			33,400		(5,235	)		35,792
Selling, general and administrative expenses		2,871		—			12,482		(670	)		14,683
Depreciation and depletion		1,761		—			12,999		—			14,760
Exploration expenses, including dry holes		251		—			1,893		—			2,144
Interest expense		217		246			4,035		(4,239	)		259
Sales-based taxes		—		—			28,547		—			28,547
Other taxes and duties		29		—			36,089		—			36,118

Total costs and other deductions		53,544		246			648,406		(371,934	)		330,262

Income before income taxes		30,462		(244	)		51,038		(28,297	)		52,959
Income taxes		2		(90	)		21,649		—			21,561

Net income including noncontrolling interests		30,460		(154	)		29,389		(28,297	)		31,398
Net income attributable to noncontrolling interests		—		—			938		—			938

Net income attributable to ExxonMobil	$	30,460	$	(154	)	$	28,451	$	(28,297	)	$	30,460


	Exxon Mobil Corporation Parent Guarantor			SeaRiver Maritime Financial Holdings, Inc.			All Other Subsidiaries		Consolidating and Eliminating Adjustments			Consolidated
	(millions of dollars)
Condensed consolidated statement of income for 12 months ended December 31, 2009
Revenues and other income
Sales and other operating revenue, including sales-based taxes	$	11,352		$	—		$	290,148	$	—		$	301,500
Income from equity affiliates		19,852			7			7,060		(19,776	)		7,143
Other income		813			—			1,130		—			1,943
Intercompany revenue		30,889			4			271,663		(302,556	)		—

Total revenues and other income		62,906			11			570,001		(322,332	)		310,586

Costs and other deductions
Crude oil and product purchases		31,419			—			411,689		(290,302	)		152,806
Production and manufacturing expenses		7,811			—			30,805		(5,589	)		33,027
Selling, general and administrative expenses		2,574			—			12,852		(691	)		14,735
Depreciation and depletion		1,571			—			10,346		—			11,917
Exploration expenses, including dry holes		230			—			1,791		—			2,021
Interest expense		1,200			222			5,126		(6,000	)		548
Sales-based taxes		—			—			25,936		—			25,936
Other taxes and duties		(29	)		—			34,848		—			34,819

Total costs and other deductions		44,776			222			533,393		(302,582	)		275,809

Income before income taxes		18,130			(211	)		36,608		(19,750	)		34,777
Income taxes		(1,150	)		(81	)		16,350		—			15,119

Net income including noncontrolling interests		19,280			(130	)		20,258		(19,750	)		19,658
Net income attributable to noncontrolling interests		—			—			378		—			378

Net income attributable to ExxonMobil	$	19,280		$	(130	)	$	19,880	$	(19,750	)	$	19,280


Condensed consolidated statement of income for 12 months ended December 31, 2008
Revenues and other income
Sales and other operating revenue, including sales-based taxes	$	17,481		$	—		$	442,098	$	—		$	459,579
Income from equity affiliates		45,664			9			11,055		(45,647	)		11,081
Other income		302			—			6,397		—			6,699
Intercompany revenue		48,414			45			442,305		(490,764	)		—

Total revenues and other income		111,861			54			901,855		(536,411	)		477,359

Costs and other deductions
Crude oil and product purchases		48,346			—			669,107		(467,999	)		249,454
Production and manufacturing expenses		8,327			—			35,298		(5,720	)		37,905
Selling, general and administrative expenses		3,349			—			13,364		(840	)		15,873
Depreciation and depletion		1,552			—			10,827		—			12,379
Exploration expenses, including dry holes		192			—			1,259		—			1,451
Interest expense		3,859			207			13,143		(16,536	)		673
Sales-based taxes		—			—			34,508		—			34,508
Other taxes and duties		67			—			41,652		—			41,719

Total costs and other deductions		65,692			207			819,158		(491,095	)		393,962

Income before income taxes		46,169			(153	)		82,697		(45,316	)		83,397
Income taxes		949			(56	)		35,637		—			36,530

Net income including noncontrolling interests		45,220			(97	)		47,060		(45,316	)		46,867
Net income attributable to noncontrolling interests		—			—			1,647		—			1,647

Net income attributable to ExxonMobil	$	45,220		$	(97	)	$	45,413	$	(45,316	)	$	45,220


	Exxon Mobil Corporation Parent Guarantor			SeaRiver Maritime Financial Holdings, Inc.			All Other Subsidiaries		Consolidating and Eliminating Adjustments			Consolidated
	(millions of dollars)
Condensed consolidated balance sheet for year ended December 31, 2010
Cash and cash equivalents	$	309		$	—		$	7,516	$	—		$	7,825
Cash and cash equivalents – restricted		371			—			257		—			628
Marketable securities		—			—			2		—			2
Notes and accounts receivable – net		2,104			—			30,346		(166	)		32,284
Inventories		1,457			—			11,519		—			12,976
Other current assets		239			—			5,030		—			5,269

Total current assets		4,480			—			54,670		(166	)		58,984
Investments, advances and long-term receivables		254,781			446			454,489		(674,378	)		35,338
Property, plant and equipment – net		18,830			—			180,718		—			199,548
Other long-term assets		224			12			8,404		—			8,640
Intercompany receivables		18,186			2,457			528,405		(549,048	)		—

Total assets	$	296,501		$	2,915		$	1,226,686	$	(1,223,592	)	$	302,510

Notes and loans payable	$	1,042		$	13		$	1,732	$	—		$	2,787
Accounts payable and accrued liabilities		2,987			—			47,047		—			50,034
Income taxes payable		—			3			9,975		(166	)		9,812

Total current liabilities		4,029			16			58,754		(166	)		62,633
Long-term debt		295			2,389			9,543		—			12,227
Postretirement benefits reserves		9,660			—			9,707		—			19,367
Deferred income tax liabilities		642			107			34,401		—			35,150
Other long-term liabilities		5,632			—			14,822		—			20,454
Intercompany payables		129,404			382			419,262		(549,048	)		—

Total liabilities		149,662			2,894			546,489		(549,214	)		149,831

Earnings reinvested		298,899			(848	)		132,357		(131,509	)		298,899
Other equity		(152,060	)		869			542,000		(542,869	)		(152,060	)

ExxonMobil share of equity		146,839			21			674,357		(674,378	)		146,839
Noncontrolling interests		—			—			5,840		—			5,840

Total equity		146,839			21			680,197		(674,378	)		152,679

Total liabilities and equity	$	296,501		$	2,915		$	1,226,686	$	(1,223,592	)	$	302,510


Condensed consolidated balance sheet for year ended December 31, 2009
Cash and cash equivalents	$	449		$	—		$	10,244	$	—		$	10,693
Marketable securities		—			—			169		—			169
Notes and accounts receivable – net		2,050			—			25,858		(263	)		27,645
Inventories		1,202			—			10,351		—			11,553
Other current assets		313			—			4,862		—			5,175

Total current assets		4,014			—			51,484		(263	)		55,235
Investments, advances and long-term receivables		199,110			449			439,712		(607,606	)		31,665
Property, plant and equipment – net		18,015			—			121,101		—			139,116
Other long-term assets		207			24			7,076		—			7,307
Intercompany receivables		19,637			2,257			442,903		(464,797	)		—

Total assets	$	240,983		$	2,730		$	1,062,276	$	(1,072,666	)	$	233,323

Notes and loans payable	$	43		$	13		$	2,420	$	—		$	2,476
Accounts payable and accrued liabilities		2,779			—			38,496		—			41,275
Income taxes payable		—			2			8,571		(263	)		8,310

Total current liabilities		2,822			15			49,487		(263	)		52,061
Long-term debt		279			2,157			4,693		—			7,129
Postretirement benefits reserves		8,673			—			9,269		—			17,942
Deferred income tax liabilities		818			151			22,179		—			23,148
Other long-term liabilities		5,286			—			12,365		—			17,651
Intercompany payables		112,536			382			351,879		(464,797	)		—

Total liabilities		130,414			2,705			449,872		(465,060	)		117,931

Earnings reinvested		276,937			(694	)		109,603		(108,909	)		276,937
Other equity		(166,368	)		719			497,978		(498,697	)		(166,368	)

ExxonMobil share of equity		110,569			25			607,581		(607,606	)		110,569
Noncontrolling interests		—			—			4,823		—			4,823

Total equity		110,569			25			612,404		(607,606	)		115,392

Total liabilities and equity	$	240,983		$	2,730		$	1,062,276	$	(1,072,666	)	$	233,323


	Exxon Mobil Corporation Parent Guarantor			SeaRiver Maritime Financial Holdings, Inc			All Other Subsidiaries			Consolidating and Eliminating Adjustments			Consolidated
	(millions of dollars)
Condensed consolidated statement of cash flows for 12 months ended December 31, 2010

Cash provided by/(used in) operating activities	$	35,740		$	63		$	18,307		$	(5,697	)	$	48,413

Cash flows from investing activities
Additions to property, plant and equipment		(2,922	)		—			(23,949	)		—			(26,871	)
Sales of long-term assets		1,484			—			1,777			—			3,261
Decrease/(increase) in restricted cash and cash equivalents		(371	)		—			(257	)		—			(628	)
Net intercompany investing		(13,966	)		(200	)		13,813			353			—
All other investing, net		(672	)		—			706			—			34

Net cash provided by/(used in) investing activities		(16,447	)		(200	)		(7,910	)		353			(24,204	)

Cash flows from financing activities
Additions to short- and long-term debt		—			—			1,741			—			1,741
Reductions in short- and long-term debt		(3	)		(13	)		(8,644	)		—			(8,660	)
Additions/(reductions) in debt with three months or less maturity		997			—			(288	)		—			709
Cash dividends		(8,498	)		—			(5,697	)		5,697			(8,498	)
Common stock acquired		(13,093	)		—			—			—			(13,093	)
Net intercompany financing activity		—			—			202			(202	)		—
All other financing, net		1,164			150			(286	)		(151	)		877

Net cash provided by/(used in) financing activities		(19,433	)		137			(12,972	)		5,344			(26,924	)

Effects of exchange rate changes on cash		—			—			(153	)		—			(153	)

Increase/(decrease) in cash and cash equivalents	$	(140	)	$	—		$	(2,728	)	$	—		$	(2,868	)


Condensed consolidated statement of cash flows for 12 months ended December 31, 2009

Cash provided by/(used in) operating activities	$	27,424		$	72		$	28,024		$	(27,082	)	$	28,438

Cash flows from investing activities
Additions to property, plant and equipment		(2,686	)		—			(19,805	)		—			(22,491	)
Sales of long-term assets		228			—			1,317			—			1,545
Decrease/(increase) in restricted cash and cash equivalents		—			—			—			—			—
Net intercompany investing		(1,826	)		(209	)		1,717			318			—
All other investing, net		—			—			(1,473	)		—			(1,473	)

Net cash provided by/(used in) investing activities		(4,284	)		(209	)		(18,244	)		318			(22,419	)

Cash flows from financing activities
Additions to short- and long-term debt		—			—			1,561			—			1,561
Reductions in short- and long-term debt		(3	)		(13	)		(1,627	)		—			(1,643	)
Additions/(reductions) in debt with three months or less maturity		39			—			(110	)		—			(71	)
Cash dividends		(8,023	)		—			(27,082	)		27,082			(8,023	)
Common stock acquired		(19,703	)		—			—			—			(19,703	)
Net intercompany financing activity		—			—			168			(168	)		—
All other financing, net		988			150			(392	)		(150	)		596

Net cash provided by/(used in) financing activities		(26,702	)		137			(27,482	)		26,764			(27,283	)

Effects of exchange rate changes on cash		—			—			520			—			520

Increase/(decrease) in cash and cash equivalents	$	(3,562	)	$	—		$	(17,182	)	$	—		$	(20,744	)


	Exxon Mobil Corporation Parent Guarantor			SeaRiver Maritime Financial Holdings, Inc.			All Other Subsidiaries			Consolidating and Eliminating Adjustments			Consolidated
	(millions of dollars)
Condensed consolidated statement of cash flows for 12 months ended December 31, 2008

Cash provided by/(used in) operating activities	$	47,823		$	68		$	54,478		$	(42,644	)	$	59,725

Cash flows from investing activities
Additions to property, plant and equipment		(2,154	)		—			(17,164	)		—			(19,318	)
Sales of long-term assets		162			—			5,823			—			5,985
Decrease/(increase) in restricted cash and cash equivalents		—			—			—			—			—
Net intercompany investing		(502	)		(155	)		476			181			—
All other investing, net		—			—			(2,166	)		—			(2,166	)

Net cash provided by/(used in) investing activities		(2,494	)		(155	)		(13,031	)		181			(15,499	)

Cash flows from financing activities
Additions to short- and long-term debt		—			—			1,146			—			1,146
Reductions in short- and long-term debt		(4	)		(13	)		(1,799	)		—			(1,816	)
Additions/(reductions) in debt with three months or less maturity		—			—			143			—			143
Cash dividends		(8,058	)		—			(42,644	)		42,644			(8,058	)
Common stock acquired		(35,734	)		—			—			—			(35,734	)
Net intercompany financing activity		—			—			81			(81	)		—
All other financing, net		1,085			100			(793	)		(100	)		292

Net cash provided by/(used in) financing activities		(42,711	)		87			(43,866	)		42,463			(44,027	)

Effects of exchange rate changes on cash		—			—			(2,743	)		—			(2,743	)

Increase/(decrease) in cash and cash equivalents	$	2,618		$	—		$	(5,162	)	$	—		$	(2,544	)

Incentive Program

12 Months Ended

Dec. 31, 2010

Incentive Program

14. Incentive Program

The 2003 Incentive Program provides for grants of stock options, stock appreciation rights (SARs), restricted stock and other forms of award. Awards may be granted to eligible employees of the Corporation and those affiliates at least 50 percent owned. Outstanding awards are subject to certain forfeiture provisions contained in the program or award instrument. The maximum number of shares of stock that may be issued under the 2003 Incentive Program is 220 million. Awards that are forfeited or expire, or are settled in cash, do not count against this maximum limit. The 2003 Incentive Program does not have a specified term. New awards may be made until the available shares are depleted, unless the Board terminates the plan early. At the end of 2010, remaining shares available for award under the 2003 Incentive Program were 141,939 thousand.

As under earlier programs, options and SARs may be granted at prices not less than 100 percent of market value on the date of grant and have a maximum life of 10 years. Most of the options and SARs normally first become exercisable one year following the date of grant. All remaining stock options and SARs outstanding were either granted prior to 2002 or were converted XTO stock options as a result of the XTO merger.

Under the terms of the XTO merger agreement, outstanding XTO stock-based awards were converted into ExxonMobil stock-based awards based on the merger exchange ratio. The converted XTO awards, granted under XTO's 1998 or 2004 Stock Incentive Plans, include restricted stock awards, stock options and performance stock awards. The grant date for the converted XTO awards is considered to be the effective date of the merger for purposes of calculating fair value. Compensation cost for the converted XTO awards is recognized in income over the requisite service period. The maximum term of the XTO awards is ten years under the 1998 plan and seven years under the 2004 plan. No additional awards will be issued under either XTO plan. In connection with the closing of the merger, the Corporation also made new grants of restricted stock under the Corporation's 2003 Incentive Program to certain current or former XTO employees as described in more detail below.

Restricted Stock. Excluding XTO merger-related grants, long-term incentive awards totaling 10,648 thousand of restricted (nonvested) common stock and restricted (nonvested) common stock units were granted in 2010. Awards totaling 10,133 thousand and 10,116 thousand of restricted (nonvested) common stock and restricted (nonvested) common stock units were granted in 2009 and 2008, respectively. These shares are issued to employees from treasury stock. The total compensation expense is recognized over the requisite service period. The units that are settled in cash are recorded as liabilities and their changes in fair value are recognized over the vesting period. During the applicable restricted periods, the shares may not be sold or transferred and are subject to forfeiture. The majority of the awards have graded vesting periods, with 50 percent of the shares in each award vesting after three years and the remaining 50 percent vesting after seven years. A small number of awards granted to certain senior executives have vesting periods of five years for 50 percent of the award and of 10 years or retirement, whichever occurs later, for the remaining 50 percent of the award.

Additionally, long-term incentive awards totaling 4,206 thousand of restricted (nonvested) common stock were granted in 2010 in association with the XTO merger. This included the granting of 1,423 thousand of restricted common stock awards under the Corporation's 2003 Incentive Program and 2,783 thousand of converted XTO restricted common stock awards. The majority of the converted XTO awards vest in three installments over a period of three years or three and a half years after the initial grant. The remainder of converted XTO awards that were granted to certain senior XTO employees will vest on the first anniversary of the effective date of the merger. Awards granted to certain former senior executives of XTO in connection with consulting agreements negotiated as part of the merger have vesting periods of one year for 50 percent of the award and of two or three years for the remaining 50 percent of the award, depending on the actual term of the consulting engagements.

The Corporation has purchased shares in the open market and through negotiated transactions to offset shares issued in conjunction with benefit plans and programs. Purchases may be discontinued at any time without prior notice.

In 2002, the Corporation began issuing restricted stock as stock-based compensation in lieu of stock options. Compensation expense for these awards is based on the price of the stock at the date of grant and has been recognized in income over the requisite service period. Prior to 2002, the Corporation issued stock options as stock-based compensation and since these awards vested prior to the effective date of current authoritative guidance, they continue to be accounted for under the prior prescribed method. Under this method, compensation expense for awards granted in the form of stock options is measured at the intrinsic value of the options (the difference between the market price of the stock and the exercise price of the options) on the date of grant. Since these two prices were the same on the date of grant, no compensation expense has been recognized in income for these awards.

The following tables summarize information about restricted stock and restricted stock units for the year ended December 31, 2010.


	2010
Restricted stock and units outstanding	Shares			Weighted Average Grant-Date Fair Value per Share
	(thousands)
Issued and outstanding at January 1		43,503		$	67.52
2009 award issued in 2010		10,132		$	75.40
Merger-related granted and converted XTO awards		4,206		$	59.31
Vested		(10,377	)	$	61.72
Forfeited		(158	)	$	67.91

Issued and outstanding at December 31		47,306		$	69.74


Value of restricted stock and units	2010		2009		2008
Grant price	$	66.07	$	75.40	$	78.24
Value at date of grant:		(millions of dollars)
Restricted stock and units settled in stock	$	672	$	711	$	735
Merger-related granted and converted XTO awards		250		—		—
Units settled in cash		60		53		56

Total value	$	982	$	764	$	791

As of December 31, 2010, there was $2,133 million of unrecognized compensation cost related to the nonvested restricted awards. This cost is expected to be recognized over a weighted-average period of 4.3 years. The compensation cost charged against income for the restricted stock and restricted units was $801 million, $723 million and $648 million for 2010, 2009 and 2008, respectively. The income tax benefit recognized in income related to this compensation expense was $81 million, $76 million and $75 million for the same periods, respectively. The fair value of shares and units vested in 2010, 2009 and 2008 was $718 million, $763 million and $438 million, respectively. Cash payments of $42 million, $41 million and $25 million for vested restricted stock units settled in cash were made in 2010, 2009 and 2008, respectively.

Performance Stock. The Corporation granted 157 thousand of converted XTO performance stock awards with a grant-date fair value of $5 million as a result of the merger. Compensation cost for the performance stock awards is based on the estimated grant-date fair value Vesting of XTO performance stock awards depended on the achievement of certain XTO stock thresholds. Upon conversion of these awards to ExxonMobil performance stock awards in connection with the merger, the performance thresholds were adjusted to equivalent market price thresholds for common stock of the Corporation. The performance stock awards are subject to forfeiture if the performance criteria are not met within the maximum term. Otherwise, holders of performance stock awards generally have all voting, dividend and other rights of other common stockholders.

The following table provides information about these converted performance stock awards as of December 31, 2010.


	Dec, 31, 2010
Performance stock awards	Shares
	(thousands)
Vesting Price:
$108.49		38
$119.76		38

During 2010, 80 thousand performance share awards vested.

Unrecognized compensation cost was $1 million at December 31, 2010. Compensation expense recognized in 2010 was $3 million.

Stock Options. The Corporation granted 12,393 thousand of converted XTO stock options with a grant-date fair value of $182 million as a result of the XTO merger. The grant included 893 thousand of unvested options. The converted XTO stock option awards are accounted for under current authoritative guidance, which requires the measurement and recognition of compensation expense based on estimated grant-date fair values. Upon conversion of these stock options to ExxonMobil stock options in connection with the merger, the performance thresholds were adjusted to equivalent market price thresholds for common stock of the Corporation. These stock options generally vest and become exercisable ratably over a three-year period, and may include a provision for accelerated vesting when the common stock price reaches specified levels. Some stock option tranches vest only when the common stock price reaches specified levels. As of December 31, 2010, unvested stock options of 574 thousand included 130 thousand options that vest ratably over three years and 444 thousand options that vest at stock prices ranging from $76.08 to $126.80.

Changes that occurred in the Corporation's stock options in 2010 are summarized below (shares in thousands):


	2010
Stock options	Shares			Avg. Exercise Price		Weighted Average Remaining Contractual Term
Outstanding at January 1		41,473		$	40.92
Merger-related converted XTO awards		12,393		$	55.15
Exercised		(24,305	)	$	43.62
Forfeited		(52	)	$	45.91

Outstanding at December 31		29,509		$	44.65		2.0 Years

Exercisable at December 31		28,935		$	43.94		1.9 Years

Unrecognized compensation cost related to the nonvested merger-related converted XTO stock options was $1 million as of December 31, 2010. Compensation expense recognized in 2010 was $2 million. No compensation expense was recognized for stock options in 2009 and 2008, as all remaining outstanding stock options were granted prior to 2002 and were fully vested. Cash received from stock option exercises was $1,043 million, $752 million and $753 million for 2010, 2009 and 2008, respectively. The cash tax benefit realized for the options exercised was $89 million, $164 million and $273 million for 2010, 2009 and 2008, respectively. The aggregate intrinsic value of stock options exercised in 2010, 2009 and 2008 was $539 million, $563 million and $894 million, respectively. The intrinsic value for the balance of outstanding stock options at December 31, 2010, was $868 million. The intrinsic value for the balance of exercisable stock options at December 31, 2010 was $865 million.

Estimated Fair Value of XTO Merger-Related Grants. For restricted stock grants, the fair value was equal to the price of the common stock on the grant date. For the converted XTO stock options and performance stock, the Corporation used a Monte Carlo simulation model to estimate fair value. The Monte Carlo simulation model requires inputs for the risk-free interest rate, dividend yield, volatility, contract term, target vesting price, post-vesting turnover rate and sub-optimal exercise factor. Expected life, derived vesting period and fair value are outputs of this model.

The risk-free interest rate is based on the constant maturity nominal rates of U.S. Treasury securities with remaining lives throughout the contract term on the day of the grant. The dividend yield is the expected common stock annual dividend yield over the expected life of the option or performance stock, expressed as a percentage of the stock price on the date of grant. The volatility factors are based on a combination of both the historical volatilities of ExxonMobil's stock and the implied volatility of traded options on ExxonMobil common stock. Estimates of fair value are not intended to predict actual future events or the value ultimately realized by certain employees who receive stock option grants, and subsequent events are not indicative of the reasonableness of the original fair value estimates.

The total estimated fair value calculated at the time of the merger for the converted XTO stock-based awards was $352 million.

Fair values were determined using the following assumptions:


Weighted average expected term			2.5 years
Range of risk-free interest rates			0.1% - 2.6%

Weighted average risk-free interest rates			0.9%
Dividend yield			3.0%

Weighted average volatility			28.5%
Range of volatility			22.5% - 33.6%

Litigation and Other Contingencies

12 Months Ended

Dec. 31, 2010

Litigation and Other Contingencies

15. Litigation and Other Contingencies

Litigation. A variety of claims have been made against ExxonMobil and certain of its consolidated subsidiaries in a number of pending lawsuits. Management has regular litigation reviews, including updates from corporate and outside counsel, to assess the need for accounting recognition or disclosure of these contingencies. The Corporation accrues an undiscounted liability for those contingencies where the incurrence of a loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. The Corporation does not record liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or when the liability is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is reasonably possible and which are significant, the Corporation discloses the nature of the contingency and, where feasible, an estimate of the possible loss. ExxonMobil will continue to defend itself vigorously in these matters. Based on a consideration of all relevant facts and circumstances, the Corporation does not believe the ultimate outcome of any currently pending lawsuit against ExxonMobil will have a materially adverse effect upon the Corporation's operations, financial condition, or financial statements taken as a whole.

Other Contingencies. The Corporation and certain of its consolidated subsidiaries were contingently liable at December 31, 2010, for $8,771 million, primarily relating to guarantees for notes, loans and performance under contracts. Included in this amount were guarantees by consolidated affiliates of $5,290 million, representing ExxonMobil's share of obligations of certain equity companies.


	Dec. 31, 2010
	Equity Company Obligations		Other Third-Party Obligations		Total
	(millions of dollars)

Guarantees	$	5,290	$	3,481	$	8,771

Additionally, the Corporation and its affiliates have numerous long-term sales and purchase commitments in their various business activities, all of which are expected to be fulfilled with no adverse consequences material to the Corporation's operations or financial condition. Unconditional purchase obligations as defined by accounting standards are those long-term commitments that are noncancelable or cancelable only under certain conditions, and that third parties have used to secure financing for the facilities that will provide the contracted goods or services.


	Payments Due by Period
	2011		2012- 2015		2016 and Beyond		Total
	(millions of dollars)

Unconditional purchase obligations (1)	$	287	$	748	$	487	$	1,522

(1)

Undiscounted obligations of $1,522 million mainly pertain to pipeline throughput agreements and include $996 million of obligations to equity companies. The present value of these commitments, which excludes imputed interest of $273 million, totaled $1,249 million.

In accordance with a nationalization decree issued by Venezuela's president in February 2007, by May 1, 2007, a subsidiary of the Venezuelan National Oil Company (PdVSA) assumed the operatorship of the Cerro Negro Heavy Oil Project. This Project had been operated and owned by ExxonMobil affiliates holding a 41.67 percent ownership interest in the Project. The decree also required conversion of the Cerro Negro Project into a "mixed enterprise" and an increase in PdVSA's or one of its affiliate's ownership interest in the Project, with the stipulation that if ExxonMobil refused to accept the terms for the formation of the mixed enterprise within a specified period of time, the government would "directly assume the activities" carried out by the joint venture. ExxonMobil refused to accede to the terms proffered by the government, and on June 27, 2007, the government expropriated ExxonMobil's 41.67 percent interest in the Cerro Negro Project.

On September 6, 2007, affiliates of ExxonMobil filed a Request for Arbitration with the International Centre for Settlement of Investment Disputes (ICSID) invoking ICSID jurisdiction under Venezuela's Investment Law and the Netherlands-Venezuela Bilateral Investment Treaty. The ICSID Tribunal issued a decision on June 10, 2010, finding that it had jurisdiction to proceed on the basis of the Netherlands-Venezuela Bilateral Investment Treaty. The ICSID arbitration proceeding is continuing and a hearing on the merits is currently scheduled for the first quarter of 2012. An affiliate of ExxonMobil has also filed an arbitration under the rules of the International Chamber of Commerce (ICC) against PdVSA and a PdVSA affiliate for breach of their contractual obligations under certain Cerro Negro Project agreements. A hearing on the merits of the ICC arbitration concluded in September 2010 and the parties filed post-hearing briefs. At this time, the net impact of this matter on the Corporation's consolidated financial results cannot be reasonably estimated. However, the Corporation does not expect the resolution to have a material effect upon the Corporation's operations or financial condition. ExxonMobil's remaining net book investment in Cerro Negro producing assets is about $750 million.

Pension and Other Postretirement Benefits

12 Months Ended

Dec. 31, 2010

Pension and Other Postretirement Benefits

16. Pension and Other Postretirement Benefits

The benefit obligations and plan assets associated with the Corporation's principal benefit plans are measured on December 31.


	Pension Benefits												Other Postretirement Benefits
	U.S.						Non-U.S.						Other Postretirement Benefits
	2010			2009			2010			2009			2010			2009
	(percent)
Weighted-average assumptions used to determine benefit obligations at December 31
Discount rate		5.50			6.00			4.80			5.20			5.50			6.00
Long-term rate of compensation increase		5.00			5.00			5.20			5.00			5.00			5.00

	(millions of dollars)
Change in benefit obligation
Benefit obligation at January 1	$	13,981		$	13,272		$	23,344		$	19,990		$	6,748		$	6,633
Service cost		468			438			480			421			101			94
Interest cost		798			809			1,175			1,121			395			408
Actuarial loss/(gain)		553			1,126			1,672			1,280			277			(49	)
Benefits paid (1) (2)		(873	)		(1,665	)		(1,281	)		(1,174	)		(394	)		(480	)
Foreign exchange rate changes		—			—			169			1,676			26			60
Plan amendments, other		80			1			163			30			178			82

Benefit obligation at December 31	$	15,007		$	13,981		$	25,722		$	23,344		$	7,331		$	6,748


Accumulated benefit obligation at December 31	$	12,764		$	11,615		$	22,958		$	20,909		$	—		$	—

(1)

Benefit payments for funded and unfunded plans.

(2)

For 2010 and 2009, other postretirement benefits paid are net of $15 million and $28 million of Medicare subsidy receipts, respectively.

For U.S. plans, the discount rate is determined by constructing a portfolio of high-quality, noncallable bonds with cash flows that match estimated outflows for benefit payments. For major non-U.S. plans, the discount rate is determined by using bond portfolios with an average maturity approximating that of the liabilities or spot yield curves, both of which are constructed using high-quality, local-currency-denominated bonds.

The measurement of the accumulated postretirement benefit obligation assumes an initial health care cost trend rate of 6.0 percent that declines to 4.5 percent by 2015. A one-percentage-point increase in the health care cost trend rate would increase service and interest cost by $57 million and the postretirement benefit obligation by $599 million. A one-percentage-point decrease in the health care cost trend rate would decrease service and interest cost by $45 million and the post-retirement benefit obligation by $494 million.


	Pension Benefits												Other Postretirement Benefits
	U.S.						Non-U.S.						Other Postretirement Benefits
	2010			2009			2010			2009			2010			2009
	(millions of dollars)
Change in plan assets
Fair value at January 1	$	10,277		$	6,634		$	15,401		$	11,260		$	514		$	443
Actual return on plan assets		1,235			2,013			1,482			2,201			63			93
Foreign exchange rate changes		—			—			99			1,300			—			—
Company contribution		—			3,070			1,184			1,456			38			36
Benefits paid (1)		(677	)		(1,440	)		(873	)		(795	)		(59	)		(57	)
Other		—			—			(528	)		(21	)		2			(1	)

Fair value at December 31	$	10,835		$	10,277		$	16,765		$	15,401		$	558		$	514

(1)

Benefit payments for funded plans.

The funding levels of all qualified pension plans are in compliance with standards set by applicable law or regulation. As shown in the table below, certain smaller U.S. pension plans and a number of non-U.S. pension plans are not funded because local tax conventions and regulatory practices do not encourage funding of these plans. All defined benefit pension obligations, regardless of the funding status of the underlying plans, are fully supported by the financial strength of the Corporation or the respective sponsoring affiliate.


	Pension Benefits
	U.S.						Non-U.S.
	2010			2009			2010			2009
	(millions of dollars)
Assets in excess of/(less than) benefit obligation
Balance at December 31
Funded plans	$	(2,349	)	$	(1,940	)	$	(2,769	)	$	(2,085	)
Unfunded plans		(1,823	)		(1,764	)		(6,188	)		(5,858	)

Total	$	(4,172	)	$	(3,704	)	$	(8,957	)	$	(7,943	)

The authoritative guidance for defined benefit pension and other post-retirement plans requires an employer to recognize the overfunded or underfunded status of a defined benefit postretirement plan as an asset or liability in its statement of financial position and to recognize changes in that funded status in the year in which the changes occur through other comprehensive income.


	Pension Benefits												Other Postretirement Benefits
	U.S.						Non-U.S.						Other Postretirement Benefits
	2010			2009			2010			2009			2010			2009
	(millions of dollars)
Assets in excess of/(less than) benefit obligation
Balance at December 31 (1)	$	(4,172	)	$	(3,704	)	$	(8,957	)	$	(7,943	)	$	(6,773	)	$	(6,234	)


Amounts recorded in the consolidated balance sheet consist of:
Other assets	$	1		$	1		$	400		$	961		$	—		$	—
Current liabilities		(257	)		(235	)		(336	)		(348	)		(343	)		(318	)
Postretirement benefits reserves		(3,916	)		(3,470	)		(9,021	)		(8,556	)		(6,430	)		(5,916	)

Total recorded	$	(4,172	)	$	(3,704	)	$	(8,957	)	$	(7,943	)	$	(6,773	)	$	(6,234	)


Amounts recorded in accumulated other comprehensive income consist of:
Net actuarial loss/(gain)	$	5,028		$	5,830		$	7,795		$	7,036		$	1,985		$	1,878
Prior service cost		83			5			674			622			154			181

Total recorded in accumulated other comprehensive income	$	5,111		$	5,835		$	8,469		$	7,658		$	2,139		$	2,059

(1)

Fair value of assets less benefit obligation shown on the preceding page.

The long-term expected rate of return on funded assets shown below is established for each benefit plan by developing a forward-looking, long-term return assumption for each asset class, taking into account factors such as the expected real return for the specific asset class and inflation

A single, long-term rate of return is then calculated as the weighted average of the target asset allocation and the long-term return assumption for each asset class.


	Pension Benefits																		Other Postretirement
	U.S.									Non-U.S.									Benefits
	2010			2009			2008			2010			2009			2008			2010			2009			2008
	(percent)
Weighted-average assumptions used to determine net periodic benefit cost for years ended December 31
Discount rate		6.00			6.25			6.25			5.20			5.50			5.40			6.00			6.25			6.25
Long-term rate of return on funded assets		7.50			8.00			9.00			6.70			7.30			7.50			7.50			8.00			9.00
Long-term rate of compensation increase		5.00			5.00			5.00			5.00			4.70			4.50			5.00			5.00			5.00

	(millions of dollars)
Components of net periodic benefit cost
Service cost	$	468		$	438		$	378		$	480		$	421		$	434		$	101		$	94		$	100
Interest cost		798			809			729			1,175			1,121			1,152			395			408			414
Expected return on plan assets		(726	)		(656	)		(915	)		(1,010	)		(886	)		(1,200	)		(37	)		(35	)		(59	)
Amortization of actuarial loss/(gain)		525			694			239			554			648			318			147			176			197
Amortization of prior service cost		2			—			(2	)		84			79			93			52			69			76
Net pension enhancement and curtailment/settlement expense		321			485			174			9			2			32			—			—			—

Net periodic benefit cost	$	1,388		$	1,770		$	603		$	1,292		$	1,385		$	829		$	658		$	712		$	728


Changes in amounts recorded in accumulated other comprehensive income:
Net actuarial loss/(gain)	$	44		$	(231	)	$	5,275		$	1,202		$	(33	)	$	4,837		$	251		$	(107	)	$	13
Amortization of actuarial (loss)/gain		(846	)		(1,179	)		(413	)		(563	)		(650	)		(350	)		(147	)		(176	)		(197	)
Prior service cost/(credit)		80			—			—			160			69			16			26			—			—
Amortization of prior service (cost)		(2	)		—			2			(84	)		(79	)		(93	)		(52	)		(69	)		(76	)
Foreign exchange rate changes		—			—			—			96			608			(997	)		2			2			(3	)

Total recorded in other comprehensive income		(724	)		(1,410	)		4,864			811			(85	)		3,413			80			(350	)		(263	)
Total recorded in net periodic benefit cost and other comprehensive income, before tax	$	664		$	360		$	5,467		$	2,103		$	1,300		$	4,242		$	738		$	362		$	465

Costs for defined contribution plans were $347 million, $339 million and $309 million in 2010, 2009 and 2008, respectively.

A summary of the change in accumulated other comprehensive income is shown in the table below:


	Total Pension and Other Postretirement Benefits
	2010			2009			2008
	(millions of dollars)
(Charge)/credit to other comprehensive income, before tax
U.S. pension	$	724		$	1,410		$	(4,864	)
Non-U.S. pension		(811	)		85			(3,413	)
Other postretirement benefits		(80	)		350			263

Total (charge)/credit to other comprehensive income, before tax		(167	)		1,845			(8,014	)
(Charge)/credit to income tax (see note 18)		35			(591	)		2,723
(Charge)/credit to investment in equity companies		11			(133	)		(27	)

(Charge)/credit to other comprehensive income including noncontrolling interests, after tax	$	(121	)	$	1,121		$	(5,318	)
Charge/(credit) to equity of noncontrolling interests		95			93			224

(Charge)/credit to other comprehensive income attributable to ExxonMobil	$	(26	)	$	1,214		$	(5,094	)

The Corporation's investment strategy for benefit plan assets reflects a long-term view, a careful assessment of the risks inherent in various asset classes and broad diversification to reduce the risk of the portfolio. The benefit plan assets are primarily invested in passive equity and fixed income index funds to diversify risk while minimizing costs. The equity funds hold ExxonMobil stock only to the extent necessary to replicate the relevant equity index. The fixed income funds are largely invested in high-quality corporate and government debt securities.

Studies are periodically conducted to establish the preferred target asset allocation. The target asset allocation for the U.S. benefit plans is 60% equity securities and 40% debt securities. The target asset allocation for the non-U.S. plans in aggregate is 56% equities, 41% debt and 3% real estate funds. The equity targets for the U.S. and non-U.S. plans include an allocation to private equity partnerships that primarily focus on early-stage venture capital of 5% and 3%, respectively.

The fair value measurement levels are accounting terms that refer to different methods of valuing assets. The terms do not represent the relative risk or credit quality of an investment.

The 2010 fair value of the benefit plan assets, including the level within the fair value hierarchy, is shown in the tables below:


	U.S. Pension										Non-U.S. Pension
	Fair Value Measurement at December 31, 2010, Using:										Fair Value Measurement at December 31, 2010, Using:
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total
	(millions of dollars)										(millions of dollars)
Asset category:
Equity securities
U.S.	$	—	$	2,648	⁽¹⁾	$	—		$	2,648	$	—		$	2,443	⁽¹⁾	$	—		$	2,443
Non-U.S.		—		3,530	⁽¹⁾		—			3,530		228	⁽²⁾		6,502	⁽¹⁾		—			6,730
Private equity		—		—			408	⁽³⁾		408		—			—			315	⁽³⁾		315
Debt securities
Corporate		—		1,152	⁽⁴⁾		—			1,152		2	⁽⁵⁾		1,629	⁽⁴⁾		—			1,631
Government		—		2,847	⁽⁴⁾		—			2,847		146	⁽⁵⁾		4,709	⁽⁴⁾		—			4,855
Asset-backed		—		31	⁽⁴⁾		—			31		—			98	⁽⁴⁾		—			98
Private mortgages		—		—			128	⁽⁶⁾		128		—			—			4	⁽⁶⁾		4
Real estate funds		—		—			—			—		—			—			417	⁽⁷⁾		417
Cash		68		—			—			68		63			51	⁽⁸⁾		—			114

Total at fair value	$	68	$	10,208		$	536		$	10,812	$	439		$	15,432		$	736		$	16,607
Insurance contracts at contract value										23											158

Total plan assets									$	10,835										$	16,765

(1)

For U.S. and non-U.S. equity securities held in the form of fund units that are redeemable at the measurement date, the unit value is treated as a Level 2 input. The fair value of the securities owned by the funds is based on observable quoted prices on active exchanges, which are Level 1 inputs.

(2)

For non-U.S. equity securities held in separate accounts, fair value is based on observable quoted prices on active exchanges.

(3)

For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings.

(4)

For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions.

(5)

For corporate and government debt securities that are traded on active exchanges, fair value is based on observable quoted prices.

(6)

For private mortgages, fair value is based on proprietary credit spread matrices developed using market data and monthly surveys of active mortgage bankers.

(7)

For real estate funds, fair value is based on appraised values developed using comparable market transactions.

(8)

For cash balances that are subject to withdrawal penalties or other adjustments, the fair value is treated as a Level 2 input.


	Other Postretirement
	Fair Value Measurement at December 31, 2010, Using:
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total
	(millions of dollars)
Asset category:
Equity securities
U.S.	$	—	$	180	⁽¹⁾	$	—		$	180
Non-U.S.		—		191	⁽¹⁾		—			191
Private equity		—		—			5	⁽²⁾		5
Debt securities
Corporate		—		49	⁽³⁾		—			49
Government		—		117	⁽³⁾		—			117
Asset-backed		—		13	⁽³⁾		—			13
Private mortgages		—		—			2	⁽⁴⁾		2
Cash		1		—			—			1

Total at fair value	$	1	$	550		$	7		$	558

(1)

For U.S. and non-U.S. equity securities held in the form of fund units that are redeemable at the measurement date, the unit value is treated as a Level 2 input. The fair value of the securities owned by the funds is based on observable quoted prices on active exchanges, which are Level 1 inputs.

(2)

For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings.

(3)

For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions.

(4)

For private mortgages, fair value is based on proprietary credit spread matrices developed using market data and monthly surveys of active mortgage bankers.

The change in the fair value in 2010 of Level 3 assets that use significant unobservable inputs to measure fair value is shown in the table below:


	2010
	Pension														Other Postretirement
	U.S.					Non U.S.
	Private Equity		Private Mortgages			Private Equity			Private Mortgages			Real Estate			Private Equity		Private Mortgages
	(millions of dollars)
Fair value at January 1	$	349	$	280		$	239		$	5		$	413		$	4	$	3

Net realized gains/(losses)		—		36			(1	)		(1	)		—			—		1
Net unrealized gains/(losses)		47		(3	)		26			1			(4	)		1		—
Net purchases/(sales)		12		(185	)		51			(1	)		8			—		(2	)

Fair value at December 31	$	408	$	128		$	315		$	4		$	417		$	5	$	2

The 2009 fair value of the benefit plan assets, including the level within the fair value hierarchy, is shown in the tables below:


	U.S. Pension										Non-U.S. Pension
	Fair Value Measurement at December 31, 2009, Using:										Fair Value Measurement at December 31, 2009, Using:
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total
	(millions of dollars)										(millions of dollars)
Asset category:
Equity securities
U.S.	$	—	$	2,503	⁽¹⁾	$	—		$	2,503	$	—		$	2,244	⁽¹⁾	$	—		$	2,244
Non-U.S.		—		3,341	⁽¹⁾		—			3,341		227	⁽²⁾		5,946	⁽¹⁾		—			6,173
Private equity		—		—			349	⁽³⁾		349		—			—			239	⁽³⁾		239
Debt securities
Corporate		—		1,040	⁽⁴⁾		—			1,040		2	⁽⁵⁾		1,637	⁽⁴⁾		—			1,639
Government		—		2,570	⁽⁴⁾		—			2,570		70	⁽⁵⁾		4,217	⁽⁴⁾		—			4,287
Asset-backed		—		30	⁽⁴⁾		—			30		—			119	⁽⁴⁾		—			119
Private mortgages		—		—			280	⁽⁶⁾		280		—			—			5	⁽⁶⁾		5
Real estate funds		—		—			—			—		—			—			413	⁽⁷⁾		413
Cash		140		—			—			140		79			55	⁽⁸⁾		—			134

Total at fair value	$	140	$	9,484		$	629		$	10,253	$	378		$	14,218		$	657		$	15,253
Insurance contracts at contract value										24											148

Total plan assets									$	10,277										$	15,401

(1)

(2)

For non-U.S. equity securities held in separate accounts, fair value is based on observable quoted prices on active exchanges.

(3)

For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings.

(4)

For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions.

(5)

For corporate and government debt securities that are traded on active exchanges, fair value is based on observable quoted prices.

(6)

For private mortgages, fair value is based on proprietary credit spread matrices developed using market data and monthly surveys of active mortgage bankers.

(7)

For real estate funds, fair value is based on appraised values developed using comparable market transactions.

(8)

For cash balances that are subject to withdrawal penalties or other adjustments, the fair value is treated as a Level 2 input.


	Other Postretirement
	Fair Value Measurement at December 31, 2009, Using:
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total
	(millions of dollars)
Asset category:
Equity securities
U.S.	$	—	$	166	⁽¹⁾	$	—		$	166
Non-U.S.		—		181	⁽¹⁾		—			181
Private equity		—		—			4	⁽²⁾		4
Debt securities
Corporate		—		51	⁽³⁾		—			51
Government		—		95	⁽³⁾		—			95
Asset-backed		—		11	⁽³⁾		—			11
Private mortgages		—		—			3	⁽⁴⁾		3
Cash		3		—			—			3

Total at fair value	$	3	$	504		$	7		$	514

(1)

(2)

For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings.

(3)

For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions.

(4)

For private mortgages, fair value is based on proprietary credit spread matrices developed using market data and monthly surveys of active mortgage bankers.

The change in the fair value in 2009 of Level 3 assets that use significant unobservable inputs to measure fair value is shown in the table below:


	2009
	Pension														Other Postretirement
	U.S.						Non U.S.
	Private Equity			Private Mortgages			Private Equity			Private Mortgages		Real Estate			Private Equity		Private Mortgages
	(millions of dollars)
Fair value at January 1	$	346		$	476		$	238		$	5	$	409		$	4	$	6

Net realized gains/(losses)		4			11			(10	)		—		(7	)		—		—
Net unrealized gains/(losses)		(35	)		7			(35	)		—		(11	)		—		—
Net purchases/(sales)		34			(214	)		46			—		22			—		(3	)

Fair value at December 31	$	349		$	280		$	239		$	5	$	413		$	4	$	3

A summary of pension plans with an accumulated benefit obligation in excess of plan assets is shown in the table below:


	Pension Benefits
	U.S.				Non-U.S.
	2010		2009		2010		2009
	(millions of dollars)
For funded pension plans with an accumulated benefit obligation in excess of plan assets:
Projected benefit obligation	$	13,184	$	12,217	$	9,865	$	13,152
Accumulated benefit obligation		11,383		10,312		9,074		12,260
Fair value of plan assets		10,834		10,276		7,131		10,447

For unfunded pension plans:
Projected benefit obligation	$	1,823	$	1,764	$	6,188	$	5,858
Accumulated benefit obligation		1,381		1,303		5,413		5,180

	Pension Benefits				Other Postretirement
	U.S.		Non-U.S.		Benefits
	(millions of dollars)
Estimated 2011 amortization from accumulated other comprehensive income:
Net actuarial loss/(gain) (1)	$	835	$	615		$ 159
Prior service cost (2)		9		97		35

(1)

The Corporation amortizes the net balance of actuarial losses/(gains) as a component of net periodic benefit cost over the average remaining service period of active plan participants.

(2)

The Corporation amortizes prior service cost on a straight-line basis as permitted under authoritative guidance for defined benefit pension and other postretirement benefit plans.


	Pension Benefits				Other Postretirement Benefits
	U.S.		Non-U.S.		Gross		Medicare Subsidy Receipt
	(millions of dollars)
Contributions expected in 2011	$	270	$	1,130	$	—	$	—

Benefit payments expected in:
2011		1,454		1,299		440		23
2012		1,483		1,281		456		25
2013		1,512		1,316		474		26
2014		1,451		1,362		489		28
2015		1,392		1,393		502		29
2016 - 2020		6,079		8,325		2,662		163

Disclosures about Segments and Related Information

12 Months Ended

Dec. 31, 2010

Disclosures about Segments and Related Information

17. Disclosures about Segments and Related Information

The Upstream, Downstream and Chemical functions best define the operating segments of the business that are reported separately. The factors used to identify these reportable segments are based on the nature of the operations that are undertaken by each segment. The Upstream segment is organized and operates to explore for and produce crude oil and natural gas. The Downstream segment is organized and operates to manufacture and sell petroleum products. The Chemical segment is organized and operates to manufacture and sell petrochemicals. These segments are broadly understood across the petroleum and petrochemical industries.

These functions have been defined as the operating segments of the Corporation because they are the segments (1) that engage in business activities from which revenues are earned and expenses are incurred; (2) whose operating results are regularly reviewed by the Corporation's chief operating decision maker to make decisions about resources to be allocated to the segment and assess its performance; and (3) for which discrete financial information is available.

Earnings after income tax include special items, and transfers are at estimated market prices. Earnings for 2009 included a special charge of $140 million in the corporate and financing segment for interest related to the Valdez punitive damages award. Special items included in 2008 after-tax earnings were a $1,620 million gain in Non-U.S. Upstream on the sale of a natural gas transportation business in Germany and special charges of $460 million in the corporate and financing segment related to the Valdez litigation.

Interest expense includes non-debt-related interest expense of $41 million, $500 million and $498 million in 2010, 2009 and 2008, respectively. Higher expenses in 2009 and 2008 primarily reflect interest provisions related to the Valdez litigation.

In corporate and financing activities, interest revenue relates to interest earned on cash deposits and marketable securities.


	Upstream				Downstream						Chemical					Corporate and Financing			Corporate Total
	U.S.		Non-U.S.		U.S.			Non-U.S.			U.S.		Non-U.S.			Corporate and Financing			Corporate Total
As of December 31, 2010		(millions of dollars)
Earnings after income tax	$	4,272	$	19,825	$	770		$	2,797		$	2,422	$	2,491		$	(2,117	)	$	30,460
Earnings of equity companies included above		1,261		8,415		23			225			171		1,163			(581	)		10,677
Sales and other operating revenue (1)		8,895		26,046		93,599			206,042			13,402		22,119			22			370,125
Intersegment revenue		8,102		39,066		13,546			52,697			9,694		8,421			282			—
Depreciation and depletion expense		3,506		7,574		681			1,565			421		432			581			14,760
Interest revenue		—		—		—			—			—		—			118			118
Interest expense		20		25		1			19			1		4			189			259
Income taxes		2,219		18,627		360			560			736		347			(1,288	)		21,561
Additions to property, plant and equipment		52,300		16,937		888			1,332			247		1,733			719			74,156
Investments in equity companies		2,636		9,625		254			1,240			285		3,586			(197	)		17,429
Total assets		76,725		115,646		18,378			47,402			7,148		19,087			18,124			302,510

As of December 31, 2009
Earnings after income tax	$	2,893	$	14,214	$	(153	)	$	1,934		$	769	$	1,540		$	(1,917	)	$	19,280
Earnings of equity companies included above		1,216		5,269		(102	)		188			164		906			(498	)		7,143
Sales and other operating revenue (1)		3,406		21,355		76,467			173,404			9,962		16,885			21			301,500
Intersegment revenue		6,718		32,982		10,168			39,190			7,185		6,947			284			—
Depreciation and depletion expense		1,768		6,376		687			1,665			400		457			564			11,917
Interest revenue		—		—		—			—			—		—			179			179
Interest expense		38		27		10			18			4		1			450			548
Income taxes		1,451		15,183		(164	)		(22	)		281		(182	)		(1,428	)		15,119
Additions to property, plant and equipment		2,973		13,307		1,449			1,447			294		2,553			468			22,491
Investments in equity companies		2,440		8,864		323			1,190			259		2,873			(207	)		15,742
Total assets		24,940		102,372		17,493			45,098			7,044		17,117			19,259			233,323

As of December 31, 2008
Earnings after income tax	$	6,243	$	29,159	$	1,649		$	6,502		$	724	$	2,233		$	(1,290	)	$	45,220
Earnings of equity companies included above		1,954		7,597		(2	)		518			105		1,411			(502	)		11,081
Sales and other operating revenue (1)		6,767		32,346		116,701			265,359			14,136		24,252			18			459,579
Intersegment revenue		9,617		55,069		16,225			65,723			9,925		9,749			273			—
Depreciation and depletion expense		1,391		7,266		656			1,672			410		422			562			12,379
Interest revenue		—		—		—			—			—		—			1,400			1,400
Interest expense		47		63		9			28			3		4			519			673
Income taxes		3,451		30,654		728			1,990			177		10			(480	)		36,530
Additions to property, plant and equipment		2,699		10,545		1,550			1,552			413		1,987			572			19,318
Investments in equity companies		2,248		7,787		456			1,382			241		2,384			(40	)		14,458
Total assets		23,056		83,750		16,328			42,044			6,856		13,300			42,718			228,052


Geographic Sales and other operating revenue (1)	2010		2009		2008
	(millions of dollars)
United States	$	115,906	$	89,847	$	137,615
Non-U.S.		254,219		211,653		321,964

Total	$	370,125	$	301,500	$	459,579


Significant non-U.S. revenue sources include:
Canada	$	27,243	$	21,151	$	33,677
Japan		27,143		22,054		30,126
United Kingdom		24,637		20,293		29,764
Belgium		21,139		16,857		25,399
Germany		14,301		14,839		20,591
Italy		14,132		12,997		17,953
France		13,920		12,042		18,530
Singapore		11,088		8,400		11,059


Long-lived assets	2010		2009		2008
	(millions of dollars)
United States	$	86,021	$	37,138	$	35,548
Non-U.S.		113,527		101,978		85,798

Total	$	199,548	$	139,116	$	121,346


Significant non-U.S. long-lived assets include:
Canada	$	20,879	$	15,919	$	12,018
Nigeria		11,429		11,046		9,227
Singapore		8,610		7,238		5,113
Angola		8,570		7,320		6,129
Norway		6,988		7,251		5,856
Australia		6,570		4,247		2,857
United Kingdom		6,177		7,609		5,778
Kazakhstan		5,938		4,748		3,535

(1)

Sales and other operating revenue includes sales-based taxes of $28,547 million for 2010, $25,936 million for 2009 and $34,508 million for 2008.

See note 1, Summary of Accounting Policies.

Income, Sales-Based and Other Taxes

12 Months Ended

Dec. 31, 2010

Income, Sales Based and Other Taxes

18. Income, Sales-Based and Other Taxes


	2010								2009									2008
	U.S.		Non-U.S.			Total			U.S.			Non-U.S.			Total			U.S.		Non-U.S.		Total
Income taxes		(millions of dollars)
Federal and non-U.S.
Current	$	1,224	$	21,093		$	22,317		$	(838	)	$	15,830		$	14,992		$	3,005	$	31,377	$	34,382
Deferred – net		49		(1,191	)		(1,142	)		650			(665	)		(15	)		168		1,289		1,457
U.S. tax on non-U.S. operations		46		—			46			32			—			32			230		—		230

Total federal and non-U.S.		1,319		19,902			21,221			(156	)		15,165			15,009			3,403		32,666		36,069
State		340		—			340			110			—			110			461		—		461

Total income taxes		1,659		19,902			21,561			(46	)		15,165			15,119			3,864		32,666		36,530
Sales-based taxes		6,182		22,365			28,547			6,271			19,665			25,936			6,646		27,862		34,508
All other taxes and duties
Other taxes and duties		776		35,342			36,118			581			34,238			34,819			1,663		40,056		41,719
Included in production and manufacturing expenses		1,001		1,237			2,238			699			1,318			2,017			915		1,720		2,635
Included in SG&A expenses		201		570			771			197			538			735			209		660		869

Total other taxes and duties		1,978		37,149			39,127			1,477			36,094			37,571			2,787		42,436		45,223

Total	$	9,819	$	79,416		$	89,235		$	7,702		$	70,924		$	78,626		$	13,297	$	102,964	$	116,261

All other taxes and duties include taxes reported in production and manufacturing and selling, general and administrative (SG&A) expenses. The above provisions for deferred income taxes include a net charge of $175 million in 2010 and net credits of $9 million in 2009 and $300 million in 2008 for the effect of changes in tax laws and rates.

Income taxes (charged)/credited directly to equity were:


	2010			2009			2008
	(millions of dollars)
Cumulative foreign exchange translation adjustment	$	(42	)	$	(247	)	$	360
Postretirement benefits reserves adjustment:
Net actuarial loss/(gain)		553			(94	)		3,361
Amortization of actuarial loss/(gain)		(609	)		(649	)		(317	)
Prior service cost		92			20			4
Amortization of prior service cost		(45	)		(43	)		(51	)
Foreign exchange rate changes		44			175			(274	)

Total postretirement benefits reserves adjustment		35			(591	)		2,723
Other components of equity		246			140			315

The reconciliation between income tax expense and a theoretical U.S. tax computed by applying a rate of 35 percent for 2010, 2009 and 2008 is as follows:


	2010			2009			2008
	(millions of dollars)
Income before income taxes
United States	$	7,711		$	2,576		$	10,152
Non-U.S.		45,248			32,201			73,245

Total	$	52,959		$	34,777		$	83,397

Theoretical tax	$	18,536		$	12,172		$	29,189
Effect of equity method of accounting		(3,737	)		(2,500	)		(3,878	)
Non-U.S. taxes in excess of theoretical U.S. tax		7,293			5,948			10,188
U.S. tax on non-U.S. operations		46			32			230
State taxes, net of federal tax benefit		221			72			300
Other U.S.		(798	)		(605	)		501

Total income tax expense	$	21,561		$	15,119		$	36,530


Effective tax rate calculation
Income taxes	$	21,561		$	15,119		$	36,530
ExxonMobil share of equity company income taxes		4,058			2,489			4,001

Total income taxes		25,619			17,608			40,531
Net income including noncontrolling interests		31,398			19,658			46,867

Total income before taxes	$	57,017		$	37,266		$	87,398


Effective income tax rate		45	%		47	%		46	%

Deferred income taxes reflect the impact of temporary differences between the amount of assets and liabilities recognized for financial reporting purposes and such amounts recognized for tax purposes.

Deferred tax liabilities/(assets) are comprised of the following at December 31:


Tax effects of temporary differences for:	2010			2009
	(millions of dollars)
Property, plant and equipment	$	42,657		$	29,931
Other liabilities		4,278			4,102

Total deferred tax liabilities	$	46,935		$	34,033


Pension and other postretirement benefits	$	(5,634	)	$	(5,442	)
Asset retirement obligations		(4,461	)		(3,978	)
Tax loss carryforwards		(3,243	)		(3,693	)
Other assets		(6,070	)		(4,700	)

Total deferred tax assets	$	(19,408	)	$	(17,813	)

Asset valuation allowances		1,183			1,495

Net deferred tax liabilities	$	28,710		$	17,715

Deferred income tax (assets) and liabilities are included in the balance sheet as shown below. Deferred income tax (assets) and liabilities are classified as current or long term consistent with the classification of the related temporary difference – separately by tax jurisdiction.


Balance sheet classification	2010			2009
	(millions of dollars)
Other current assets	$	(3,359	)	$	(3,322	)
Other assets, including intangibles, net		(3,527	)		(2,263	)
Accounts payable and accrued liabilities		446			152
Deferred income tax liabilities		35,150			23,148

Net deferred tax liabilities	$	28,710		$	17,715

The Corporation had $35 billion of indefinitely reinvested, undistributed earnings from subsidiary companies outside the U.S. Unrecognized deferred taxes on remittance of these funds are not expected to be material.

Unrecognized Tax Benefits

The Corporation is subject to income taxation in many jurisdictions around the world. Unrecognized tax benefits reflect the difference between positions taken or expected to be taken on income tax returns and the amounts recognized in the financial statements. Resolution of the related tax positions through negotiations with the relevant tax authorities or through litigation will take many years to complete. It is difficult to predict the timing of resolution for tax positions since such timing is not entirely within the control of the Corporation. It is reasonably possible that the total amount of unrecognized tax benefits could increase by up to 20 percent or decrease by up to 5 percent in the next 12 months. Given the long time periods involved in resolving tax positions, the Corporation does not expect that the recognition of unrecognized tax benefits will have a material impact on the Corporation's effective income tax rate in any given year.

The following table summarizes the movement in unrecognized tax benefits.


Gross unrecognized tax benefits	2010			2009			2008
	(millions of dollars)
Balance at January 1	$	4,725		$	4,976		$	5,232
Additions based on current year's tax positions		830			547			656
Additions for prior years' tax positions		620			262			294
Reductions for prior years' tax positions		(505	)		(594	)		(328	)
Reductions due to lapse of the statute of limitations		(534	)		—			(27	)
Settlements with tax authorities		(999	)		(592	)		(681	)
Foreign exchange effects/other		11			126			(170	)

Balance at December 31	$	4,148		$	4,725		$	4,976

The additions and reductions in unrecognized tax benefits shown above include effects related to net income and equity, and timing differences for which the ultimate deductibility is highly certain but for which there is uncertainty about the timing of such deductibility. The 2010, 2009 and 2008 changes in unrecognized tax benefits did not have a material effect on the Corporation's net income or cash flow.

The following table summarizes the tax years that remain subject to examination by major tax jurisdiction:


Country of Operation		Open Tax Years
Abu Dhabi		2000 - 2010
Angola		2007 - 2010
Australia		2000 - 2010
Canada		1994 - 2010
Equatorial Guinea		2005 - 2010
Germany		1999 - 2010
Japan		2003 - 2010
Malaysia		2004 - 2010
Nigeria		1998 - 2010
Norway		2000 - 2010
United Kingdom		2004 - 2010
United States:		1991 - 1996
		1998 - 2000
		2004 - 2010

The Corporation classifies interest on income tax-related balances as interest expense or interest income and classifies tax-related penalties as operating expense.

In 2010, the Corporation's resolution of certain tax positions with tax jurisdictions resulted in a decrease in the total amount of unrecognized tax benefits and the related interest payable. For 2010, net interest expense was a credit of $39 million, reflecting the effect of credits from the net favorable resolution of these prior year tax positions. The Corporation incurred approximately $135 million and $137 million in interest expense on income tax reserves in 2009 and 2008, respectively. The related interest payable balances were $636 million and $771 million at December 31, 2010, and 2009, respectively.

Acquisition of XTO Energy Inc.

12 Months Ended

Dec. 31, 2010

Acquisition of XTO Energy Inc.

19. Acquisition of XTO Energy Inc.

Description of the Transaction. On June 25, 2010, ExxonMobil acquired XTO Energy Inc. (XTO) by merging a wholly-owned subsidiary of ExxonMobil with and into XTO (the "merger"), with XTO continuing as the surviving corporation and wholly-owned subsidiary of ExxonMobil. XTO is involved in the exploration for, production of, and transportation and sale of crude oil and natural gas. XTO's asset base, technical capabilities and operating expertise, together with ExxonMobil's extensive research and development expertise, project management and operational skills, global scale and financial capacity, should enable effective development of additional supplies of unconventional oil and gas resources.

At the effective time of the merger, each share of XTO common stock was converted into the right to receive 0.7098 shares of common stock of ExxonMobil (the "Exchange Ratio"), with cash being paid in lieu of any fractional shares of ExxonMobil stock. Also at the effective time, each outstanding option to purchase XTO common stock was converted into an option to purchase a number of shares of ExxonMobil stock based on the Exchange Ratio, and each outstanding restricted stock award and performance stock award of XTO was converted into a restricted stock award or performance stock award, as applicable, of ExxonMobil stock based on the Exchange Ratio.

The components of the consideration transferred follow:


	(millions of dollars)

Consideration attributable to stock issued (1) (2)	$	24,480
Consideration attributable to converted stock options (2)		179

Total consideration transferred	$	24,659

(1)

The fair value of the Corporation's common stock on the acquisition date was $59.10 per share based on the closing value on the NYSE. The Corporation issued 416 million shares of stock previously held in treasury. The treasury stock issued, based on the average cost, was valued at $21,139 million. The excess of the fair value of the consideration transferred over the cost of treasury stock issued was $3,520 million and was included in common stock without par value.

(2)	The portion of the fair value of XTO converted stock-based awards attributable to pre-merger employee service was part of consideration. The remaining fair value of the awards will be recognized in future periods over the requisite service period.

Recording of Assets Acquired and Liabilities Assumed. The transaction was accounted for using the acquisition method of accounting, which requires, among other things, that assets acquired and liabilities assumed be recognized at their fair values as of the acquisition date.

The following table summarizes the assets acquired and liabilities assumed:


	(millions of dollars)
Cash and cash equivalents	$	47
Notes and accounts receivable		925
Inventories		170
Other current assets (1)		911
Investments, advances and long-term receivables		52
Property, plant and equipment (2)		47,300
Identifiable intangible assets (3)		493
Goodwill (4)		39
Other assets (1)		75

Total assets acquired	$	50,012


Notes and loans payable (5)	$	1,026
Accounts payable and accrued liabilities (1) (6)		1,788
Income taxes payable		(199	)
Long-term debt (5)		10,574
Postretirement benefits reserves		65
Deferred income tax liabilities (6)		11,204
Other long-term obligations		895

Total liabilities assumed	$	25,353

Net assets acquired	$	24,659

(1)	Derivatives were measured using Level 1 inputs for derivatives that are traded directly on the NYMEX and Level 2 inputs for derivatives that are determined by either market prices on an active market for similar assets or by prices quoted by a broker or other market-corroborated prices.

(2)

Property, plant and equipment were measured primarily using an income approach. The fair value measurements of the oil and gas assets were based, in part, on significant inputs not observable in the market and thus represent a Level 3 measurement. The significant inputs included XTO resources, assumed future production profiles, commodity prices (mainly based on observable market inputs), risk adjusted discount rate of 7.0 percent, inflation of 2.0 percent and assumptions on the timing and amount of future development and operating costs. The property, plant and equipment additions were segmented to the Upstream business, with substantially all of the assets in the United States.

(3)	Identifiable intangible assets and other assets were measured using a combination of an income approach and a market approach (Level 3). Identifiable intangible assets will be amortized over 20 years.

(4)

Goodwill was the excess of the consideration transferred over the net assets recognized and represents the future economic benefits arising from other assets acquired that could not be individually identified and separately recognized. Goodwill was recognized in the Upstream reporting unit. Goodwill is not amortized and is not deductible for tax purposes.

(5)	Long-term debt was recognized mainly at market rates at closing (Level 1).

(6)	Deferred income taxes reflect the temporary differences between the amount of assets and liabilities recognized for financial reporting purposes and such amounts recognized for tax purposes.

XTO Results and Pro Forma Impact of Merger. The following table presents revenues and earnings for XTO for the periods presented:


	Acquisition Date Through December 31, 2010
	(millions of dollars)
Revenues	$	4,448

Upstream earnings	$	262

Transaction-related costs were expensed as incurred. The Corporation recognized $18 million in transaction costs related to the merger in 2010.

The following table presents unaudited pro forma information for the Corporation as if the merger of XTO had occurred at the beginning of each year presented:


	2010		2009
	(millions of dollars, except per share amounts)

Revenues	$	373,273	$	307,456

Net income attributable to ExxonMobil	$	30,668	$	19,672

Earnings per common share	$	6.03	$	3.75

Earnings per common share – assuming dilution	$	6.01	$	3.74

The historical financial information was adjusted to give effect to the pro forma events that were directly attributable to the merger and factually supportable. The unaudited pro forma consolidated results are not necessarily indicative of what the consolidated results of operations actually would have been had the merger been completed on January 1, 2010, or on January 1, 2009. In addition, the unaudited pro forma consolidated results do not purport to project the future results of operations of the combined company. The unaudited pro forma consolidated results reflect pro forma adjustments for the elimination of deferred gains and losses recognized in earnings for derivatives outstanding at the beginning of the year presented, depreciation expense related to the fair value adjustment to property, plant and equipment acquired, additional amortization expense related to the fair value of identifiable intangible assets acquired, capitalization of interest expense and applicable income tax impacts.

Summary of Accounting Policies (Policy)	12 Months Ended
Summary of Accounting Policies (Policy)	Dec. 31, 2010
Statement [Line Items]
Principles of Consolidation	Principles of Consolidation. The Consolidated Financial Statements include the accounts of those subsidiaries owned directly or indirectly with more than 50 percent of the voting rights held by the Corporation and for which other shareholders do not possess the right to participate in significant management decisions. They also include the Corporation's share of the undivided interest in certain upstream assets and liabilities. Amounts representing the Corporation's percentage interest in the underlying net assets of other subsidiaries and less-than-majority-owned companies in which a significant ownership percentage interest is held are included in "Investments, advances and long-term receivables"; the Corporation's share of the net income of these companies is included in the Consolidated Statement of Income caption "Income from equity affiliates." The Corporation's share of the cumulative foreign exchange translation adjustment for equity method investments is reported in the Consolidated Statement of Changes in Equity. Evidence of loss in value that might indicate impairment of investments in companies accounted for on the equity method is assessed to determine if such evidence represents a loss in value of the Corporation's investment that is other than temporary. Examples of key indicators include a history of operating losses, a negative earnings and cash flow outlook, significant downward revisions to oil and gas reserves, and the financial condition and prospects for the investee's business segment or geographic region. If evidence of an other than temporary loss in fair value below carrying amount is determined, an impairment is recognized. In the absence of market prices for the investment, discounted cash flows are used to assess fair value.
Revenue Recognition	Revenue Recognition. The Corporation generally sells crude oil, natural gas and petroleum and chemical products under short-term agreements at prevailing market prices. In some cases (e.g., natural gas), products may be sold under long-term agreements, with periodic price adjustments. In all cases, revenues are recognized when the products are delivered, which occurs when the customer has taken title and has assumed the risks and rewards of ownership, prices are fixed or determinable and collectibility is reasonably assured. Revenues from the production of natural gas properties in which the Corporation has an interest with other producers are recognized on the basis of the Corporation's net working interest. Differences between actual production and net working interest volumes are not significant. Purchases and sales of inventory with the same counterparty that are entered into in contemplation of one another are combined and recorded as exchanges measured at the book value of the item sold.
Sales-Based Taxes	Sales-Based Taxes. The Corporation reports sales, excise and value-added taxes on sales transactions on a gross basis in the Consolidated Statement of Income (included in both revenues and costs). This gross reporting basis is footnoted on the Consolidated Statement of Income.
Derivative Instruments	Derivative Instruments. The Corporation makes limited use of derivative instruments. The Corporation does not engage in speculative derivative activities or derivative trading activities, nor does it use derivatives with leveraged features. When the Corporation does enter into derivative transactions, it is to offset exposures associated with interest rates, foreign currency exchange rates and hydrocarbon prices that arise from existing assets, liabilities and forecasted transactions. For derivatives designated as cash flow hedges, the Corporation's activity is intended to manage the price risk posed by physical transactions. The Corporation records all derivatives on the balance sheet at fair value. The change in fair value of derivatives designated as fair value hedges is recognized in earnings, offset by the change in fair value of the hedged item. The change in fair value of derivatives designated as cash flow hedges is recorded in other comprehensive income and recognized in earnings when the hedged transaction is recognized in earnings. The change in fair value of derivatives not designated as hedging instruments is recognized in earnings. Any ineffectiveness between the derivative and the hedged item is recorded in earnings. Hedge effectiveness is reviewed at least quarterly and is generally based on the most recent relevant correlation between the derivative and the item hedged. Hedge ineffectiveness is calculated based on the difference between the change in fair value of the derivative and change in cash flow or fair value of the items hedged. If it is determined that a derivative is no longer highly effective, hedge accounting is then discontinued and the change in fair value since inception that is on the balance sheet either as other comprehensive income for cash flow hedges, or the underlying hedged item for fair value hedges, is recorded in earnings.
Fair Value	Fair Value. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 or 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market.
Inventories	Inventories. Crude oil, products and merchandise inventories are carried at the lower of current market value or cost (generally determined under the last-in, first-out method – LIFO). Inventory costs include expenditures and other charges (including depreciation) directly and indirectly incurred in bringing the inventory to its existing condition and location. Selling expenses and general and administrative expenses are reported as period costs and excluded from inventory cost. Inventories of materials and supplies are valued at cost or less.
Property, Plant and Equipment	Property, Plant and Equipment. Depreciation, depletion and amortization, based on cost less estimated salvage value of the asset, are primarily determined under either the unit-of-production method or the straight-line method, which is based on estimated asset service life taking obsolescence into consideration. Maintenance and repairs, including planned major maintenance, are expensed as incurred. Major renewals and improvements are capitalized and the assets replaced are retired. Interest costs incurred to finance expenditures during the construction phase of multiyear projects are capitalized as part of the historical cost of acquiring the constructed assets. The project construction phase commences with the development of the detailed engineering design and ends when the constructed assets are ready for their intended use. Capitalized interest costs are included in property, plant and equipment and are depreciated over the service life of the related assets. The Corporation uses the "successful efforts" method to account for its exploration and production activities. Under this method, costs are accumulated on a field-by-field basis with certain exploratory expenditures and exploratory dry holes being expensed as incurred. Costs of productive wells and development dry holes are capitalized and amortized on the unit-of-production method. The Corporation carries as an asset exploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and where the Corporation is making sufficient progress assessing the reserves and the economic and operating viability of the project. Exploratory well costs not meeting these criteria are charged to expense. Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves. Significant unproved properties are assessed for impairment individually and valuation allowances against the capitalized costs are recorded based on the estimated economic chance of success and the length of time that the Corporation expects to hold the properties. Properties that are not individually significant are aggregated by groups and amortized based on development risk and average holding period. The valuation allowances are reviewed at least annually. Other exploratory expenditures, including geophysical costs, other dry hole costs and annual lease rentals, are expensed as incurred. Unit-of-production depreciation is applied to property, plant and equipment, including capitalized exploratory drilling and development costs, associated with productive depletable extractive properties in the Upstream segment. Unit-of-production rates are based on the amount of proved developed reserves of oil, gas and other minerals that are estimated to be recoverable from existing facilities using current operating methods. Under the unit-of-production method, oil and gas volumes are considered produced once they have been measured through meters at custody transfer or sales transaction points at the outlet valve on the lease or field storage tank. Production costs are expensed as incurred. Production involves lifting the oil and gas to the surface and gathering, treating, field processing and field storage of the oil and gas. The production function normally terminates at the outlet valve on the lease or field production storage tank. Production costs are those incurred to operate and maintain the Corporation's wells and related equipment and facilities. They become part of the cost of oil and gas produced. These costs, sometimes referred to as lifting costs, include such items as labor costs to operate the wells and related equipment; repair and maintenance costs on the wells and equipment; materials, supplies and energy costs required to operate the wells and related equipment; and administrative expenses related to the production activity. Gains on sales of proved and unproved properties are only recognized when there is no uncertainty about the recovery of costs applicable to any interest retained or where there is no substantial obligation for future performance by the Corporation. Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value. Proved oil and gas properties held and used by the Corporation are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recoverable. Assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. The Corporation estimates the future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. Cash flows used in impairment evaluations are developed using annually updated corporate plan investment evaluation assumptions for crude oil commodity prices and foreign currency exchange rates. Annual volumes are based on individual field production profiles, which are also updated annually. Prices for natural gas and other products are based on corporate plan assumptions developed annually by major region and also for investment evaluation purposes. Cash flow estimates for impairment testing exclude derivative instruments. Impairment analyses are generally based on proved reserves. Where probable reserves exist, an appropriately risk-adjusted amount of these reserves may be included in the impairment evaluation. Impairments are measured by the amount the carrying value exceeds the fair value.
Goodwill	Goodwill. Goodwill is the excess of the consideration transferred over the value of net assets recognized and represents the future economic benefits arising from other assets acquired that could not be individually identified and separately recognized. Goodwill is evaluated for impairment on at least an annual basis.
Asset Retirement Obligations and Environmental Liabilities	Asset Retirement Obligations and Environmental Liabilities. The Corporation incurs retirement obligations for certain assets at the time they are installed. The fair values of these obligations are recorded as liabilities on a discounted basis. The costs associated with these liabilities are capitalized as part of the related assets and depreciated. Over time, the liabilities are accreted for the change in their present value. Liabilities for environmental costs are recorded when it is probable that obligations have been incurred and the amounts can be reasonably estimated. These liabilities are not reduced by possible recoveries from third parties and projected cash expenditures are not discounted.
Foreign Currency Translation	Foreign Currency Translation. The Corporation selects the functional reporting currency for its international subsidiaries based on the currency of the primary economic environment in which each subsidiary operates. Downstream and Chemical operations primarily use the local currency. However, the U.S. dollar is used in countries with a history of high inflation (primarily in Latin America) and Singapore, which predominantly sells into the U.S. dollar export market. Upstream operations which are relatively self-contained and integrated within a particular country, such as Canada, the United Kingdom, Norway and continental Europe, use the local currency. Some Upstream operations, primarily in Asia and Africa, use the U.S. dollar because they predominantly sell crude and natural gas production into U.S. dollar-denominated markets. For all operations, gains or losses from remeasuring foreign currency transactions into the functional currency are included in income.
Stock-Based Payments	Stock-Based Payments. The Corporation awards stock-based compensation to employees in the form of restricted stock and restricted stock units. Compensation expense is measured by the market price of the restricted shares at the date of grant and is recognized in the income statement over the requisite service period of each award. See note 14, Incentive Program, for further details.

Miscellaneous Financial Information (Tables)

12 Months Ended

Dec. 31, 2010

Crude oil, products and merchandise


	2010		2009
	(billions of dollars)
Petroleum products	$	3.5	$	3.2
Crude oil		3.8		3.2
Chemical products		2.1		2.0
Gas/other		0.5		0.3

Total	$	9.9	$	8.7

Cash Flow Information (Tables)

12 Months Ended

Dec. 31, 2010

Cash payments


	2010		2009		2008
	(millions of dollars)
Cash payments for interest	$	703	$	820	$	650

Cash payments for income taxes	$	18,941	$	15,427	$	33,941

Additional Working Capital Information (Tables)

12 Months Ended

Dec. 31, 2010

Schedule of notes, accounts receivable and payable, loans payable, and accrued liabilities


	Dec. 31 2010		Dec. 31 2009
	(millions of dollars)
Notes and accounts receivable
Trade, less reserves of $152 million and $198 million	$	25,439	$	22,186
Other, less reserves of $34 million and $31 million		6,845		5,459

Total	$	32,284	$	27,645


Notes and loans payable
Bank loans	$	532	$	1,043
Commercial paper		1,346		201
Long-term debt due within one year		345		348
Other		564		884

Total	$	2,787	$	2,476


Accounts payable and accrued liabilities
Trade payables	$	30,780	$	24,236
Payables to equity companies		5,450		4,979
Accrued taxes other than income taxes		6,778		5,921
Other		7,026		6,139

Total	$	50,034	$	41,275

Equity Company Information (Tables)

12 Months Ended

Dec. 31, 2010

Schedule of equity company financial summary


	2010				2009				2008
Equity Company Financial Summary	Total		ExxonMobil Share		Total		ExxonMobil Share		Total		ExxonMobil Share
	(millions of dollars)
Total revenues	$	153,020	$	48,355	$	112,153	$	36,570	$	148,477	$	49,999

Income before income taxes	$	48,075	$	14,735	$	28,472	$	9,632	$	42,588	$	15,082
Income taxes		13,962		4,058		7,775		2,489		12,020		4,001

Income from equity affiliates	$	34,113	$	10,677	$	20,697	$	7,143	$	30,568	$	11,081


Current assets	$	48,573	$	15,860	$	37,376	$	12,843	$	29,358	$	9,920
Long-term assets		90,646		29,805		88,153		27,983		87,442		28,339

Total assets	$	139,219	$	45,665	$	125,529	$	40,826	$	116,800	$	38,259

Current liabilities	$	33,160	$	10,260	$	24,854	$	8,085	$	26,221	$	8,707
Long-term liabilities		59,596		17,976		57,384		16,999		50,895		15,094

Net assets	$	46,463	$	17,429	$	43,291	$	15,742	$	39,684	$	14,458

Schedule of the Corporation's percentage ownership interest


	Percentage Ownership Interest
Upstream
Aera Energy LLC		48
BEB Erdgas und Erdoel GmbH		50
Cameroon Oil Transportation Company S.A.		41
Castle Peak Power Company Limited		60
Golden Pass LNG Terminal LLC		18
Nederlandse Aardolie Maatschappij B.V.		50
Qatar Liquefied Gas Company Limited		10
Qatar Liquefied Gas Company Limited 2		24
Ras Laffan Liquefied Natural Gas Company Limited		25
Ras Laffan Liquefied Natural Gas Company Limited II		31
Ras Laffan Liquefied Natural Gas Company Limited (3)		30
South Hook LNG Terminal Company Limited		24
Tengizchevroil, LLP		25
Terminale GNL Adriatico S.r.l.		69

Downstream
Chalmette Refining, LLC		50
Fujian Refining & Petrochemical Co. Ltd.		25
Saudi Aramco Mobil Refinery Company Ltd.		50

Chemical
Al-Jubail Petrochemical Company		50
Infineum Holdings B.V.		50
Saudi Yanbu Petrochemical Co.		50
Toray Tonen Specialty Separator Godo Kaisha		50

Investments, Advances and Long-Term Receivables (Tables)

12 Months Ended

Dec. 31, 2010

Schedule of investments, advances and long-term receivables


	Dec. 31 2010		Dec. 31 2009
	(millions of dollars)
Companies carried at equity in underlying assets
Investments	$	17,429	$	15,742
Advances		9,286		8,669

	$	26,715	$	24,411
Companies carried at cost or less and stock investments carried at fair value		1,557		1,577

	$	28,272	$	25,988
Long-term receivables and miscellaneous investments at cost or less, net of reserves of $292 million and $368 million		7,066		5,677

Total	$	35,338	$	31,665

Property, Plant and Equipment and Asset Retirement Obligations (Tables)

12 Months Ended

Dec. 31, 2010

Property, plant and equipment


	Dec. 31, 2010				Dec. 31, 2009
Property, Plant and Equipment	Cost		Net		Cost		Net
			(millions of dollars)
Upstream	$	264,136	$	148,152	$	198,036	$	88,319
Downstream		68,652		30,095		68,092		30,499
Chemical		29,524		14,255		28,464		13,511
Other		11,626		7,046		11,314		6,787

Total	$	373,938	$	199,548	$	305,906	$	139,116

Asset retirement obligations


	2010			2009
	(millions of dollars)
Beginning balance	$	8,473		$	5,352
Accretion expense and other provisions		563			372
Reduction due to property sales		(183	)		(18	)
Payments made		(638	)		(448	)
Liabilities incurred		1,094			156
Foreign currency translation		(45	)		535
Revisions		350			2,524

Ending balance	$	9,614		$	8,473

Accounting for Suspended Exploratory Well Costs (Tables)

12 Months Ended

Dec. 31, 2010

Change in capitalized suspended exploratory well costs


	2010			2009			2008
	(millions of dollars)
Balance beginning at January 1	$	2,005		$	1,585		$	1,291
Additions pending the determination of proved reserves		1,103			624			448
Charged to expense		(104	)		(51	)		—
Reclassifications to wells, facilities and equipment based on the determination of proved reserves		(136	)		(200	)		(101	)
Other		25			47			(53	)

Ending balance	$	2,893		$	2,005		$	1,585

Ending balance attributed to equity companies included above	$	—		$	9		$	10

Period end capitalized suspended exploratory well costs


	2010		2009		2008
	(millions of dollars)
Capitalized for a period of one year or less	$	1,103	$	624	$	448
Capitalized for a period of between one and five years		1,294		924		636
Capitalized for a period of between five and ten years		278		220		225
Capitalized for a period of greater than ten years		218		237		276

Capitalized for a period greater than one year – subtotal	$	1,790	$	1,381	$	1,137

Total	$	2,893	$	2,005	$	1,585

Number of projects with suspended exploratory well costs


	2010		2009		2008
Number of projects with first capitalized well drilled in the preceding 12 months		9		18		12
Number of projects that have exploratory well costs capitalized for a period of greater than 12 months		59		57		50

Total		68		75		62

Additional detail for the 34 projects with completed exploratory activity progressing toward development


Country/Project	Dec 31, 2010		Years Wells Drilled		Comment
(millions of dollars)
Angola
- Perpetua-Zina-Acacia	$	15		2008 - 2009	Oil field near Pazflor development, awaiting capacity in existing/planned infrastructure.
Australia
- East Pilchard		10		2001	Gas field near Kipper/Tuna development, awaiting capacity in existing/planned infrastructure.
Indonesia
- Natuna		118		1981 - 1983	Development activity under way, while continuing discussions with the government on contract terms pursuant to recently executed Heads of Agreement.
Kazakhstan
- Kairan		53		2004 - 2007	Declarations involving field commerciality filed with Kazakhstan government in 2008; progressing commercialization and field development studies.
Nigeria
- Bolia		15		2002 - 2006	Evaluating development plan, while continuing discussions with the government regarding regional hub strategy.
- Bonga North		34		2004 - 2009	Pursuing alignment with operator and government regarding development plan.
- Bosi		79		2002 - 2006	Development activity under way while continuing discussions with the government regarding development plan.
- Other (5 projects)		16		2001 - 2002	Pursuing development of several additional offshore satellite discoveries which will tie back to existing/planned production facilities.
Norway
- Gamma		20		2008 - 2009	Evaluating development plan for tieback to existing production facilities.
- H-North		15		2007	Discovery near existing facilities in Fram area; evaluating development options.
- Lavrans		23		1995 - 1999	Development awaiting capacity in existing Kristin production facility; evaluating development concepts for phased ullage scenarios.
- Noatun		19		2008	Evaluating development plan for tieback to existing production facilities.
- Nyk High		20		2008	Evaluating field development alternatives.
- Other (8 projects)		34		1992 - 2009	Evaluating development plans, including potential for tieback to existing production facilities.
Papua New Guinea
- Juha		28		2007	Working on development plans to tie into planned LNG facilities.
United Kingdom
- Fram		55		2009	Progressing development and commercialization plans.
- Other (3 projects)		21		2001 - 2008	Projects primarily awaiting capacity in existing or planned infrastructure.
United States
- Julia Unit		78		2007 - 2008	Julia Unit owners are progressing development plans and have agreed to share funding on facilities at the Chevron-operated Jack-Saint Malo platform. Suspension of Production for the Julia Unit is under review by the Bureau of Ocean Energy Management, Regulation and Enforcement.
- Tip Top		31		2009	Evaluating development concept and requisite facility upgrades.
Other
- Various (2 projects)		8		1979 - 1995	Projects primarily awaiting capacity in existing or planned infrastructure.
Total 2010 (34 projects)	$	692

Leased Facilities (Tables)

12 Months Ended

Dec. 31, 2010

Leased facilities


	Lease Payments Under Minimum Commitments		Related Sublease Rental Income
	(millions of dollars)
2011	$	2,095	$	8
2012		1,570		8
2013		1,061		7
2014		731		6
2015		581		6
2016 and beyond		1,738		27

Total	$	7,776	$	62

Net rental cost


	2010		2009		2008
	(millions of dollars)
Rental cost	$	3,762	$	4,426	$	4,115
Less sublease rental income		90		98		123

Net rental cost	$	3,672	$	4,328	$	3,992

Earnings Per Share (Tables)

12 Months Ended

Dec. 31, 2010

Earnings per share computation


	2010		2009		2008
Earnings per common share

Net income attributable to ExxonMobil (millions of dollars)	$	30,460	$	19,280	$	45,220

Weighted average number of common shares outstanding (millions of shares)		4,885		4,832		5,194

Earnings per common share (dollars)	$	6.24	$	3.99	$	8.70

Earnings per common share – assuming dilution

Net income attributable to ExxonMobil (millions of dollars)	$	30,460	$	19,280	$	45,220

Weighted average number of common shares outstanding (millions of shares)		4,885		4,832		5,194
Effect of employee stock-based awards		12		16		27

Weighted average number of common shares outstanding – assuming dilution		4,897		4,848		5,221


Earnings per common share – assuming dilution (dollars)	$	6.22	$	3.98	$	8.66

Dividends paid per common share (dollars)	$	1.74	$	1.66	$	1.55

Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2010

Summarized long-term debt

	2010		2009
	(millions of dollars)
SeaRiver Maritime Financial Holdings, Inc. (1)
Guaranteed debt securities due 2011 (2)	$	—	$	13
Guaranteed deferred interest debentures due 2012 – Face value net of unamortized discount plus accrued interest		2,389		2,144
XTO Energy Inc. (premium in millions of dollars)
7.500% senior note due 2012 includes premium of $15		199		—
5.900% senior note due 2012 includes premium of $16		233		—
6.250% senior note due 2013 includes premium of $18		193		—
4.625% senior note due 2013 includes premium of $9		149		—
5.750% senior note due 2013 includes premium of $37		359		—
4.900% senior note due 2014 includes premium of $19		267		—
5.000% senior note due 2015 includes premium of $13		142		—
5.300% senior note due 2015 includes premium of $28		262		—
5.650% senior note due 2016 includes premium of $27		227		—
6.250% senior note due 2017 includes premium of $80		534		—
5.500% senior note due 2018 includes premium of $49		420		—
6.500% senior note due 2018 includes premium of $86		524		—
6.100% senior note due 2036 includes premium of $29		204		—
6.750% senior note due 2037 includes premium of $69		329		—
6.375% senior note due 2038 includes premium of $46		258		—

Mobil Services (Bahamas) Ltd.
Variable note due 2035 (3)		972		972
Variable note due 2034 (4)		311		311

Mobil Producing Nigeria Unlimited (5)
Variable notes due 2012-2017		415		621

Esso (Thailand) Public Company Ltd. (6)
Variable notes due 2012-2017		522		165

Mobil Corporation
8.625% debentures due 2021		248		248

Industrial revenue bonds due 2012-2040 (7)		2,247		1,685
Other U.S. dollar obligations (8)		454		536
Other foreign currency obligations		65		66
Capitalized lease obligations (9)		304		368

Total long-term debt	$	12,227	$	7,129

(1)

Additional information is provided for this subsidiary on the following pages.

(2)

Average effective interest rate of 1.6% in 2009.

(3)

Average effective interest rate of 0.3% in 2010 and 0.3% in 2009.

(4)

Average effective interest rate of 0.4% in 2010 and 0.9% in 2009.

(5)

Average effective interest rate of 4.6% in 2010 and 5.4% in 2009.

(6)

Average effective interest rate of 1.7% in 2010 and 2.2% in 2009.

(7)

Average effective interest rate of 0.2% in 2010 and 0.2% in 2009.

(8)

Average effective interest rate of 4.7% in 2010 and 5.0% in 2009.

(9)

Average imputed interest rate of 8.1% in 2010 and 8.8% in 2009.

Condensed consolidated statement of income


	Exxon Mobil Corporation Parent Guarantor		SeaRiver Maritime Financial Holdings, Inc.			All Other Subsidiaries		Consolidating and Eliminating Adjustments			Consolidated
	(millions of dollars)
Condensed consolidated statement of income for 12 months ended December 31, 2010
Revenues and other income
Sales and other operating revenue, including sales-based taxes	$	15,382	$	—		$	354,743	$	—		$	370,125
Income from equity affiliates		28,401		(2	)		10,589		(28,311	)		10,677
Other income		790		—			1,629		—			2,419
Intercompany revenue		39,433		4			332,483		(371,920	)		—

Total revenues and other income		84,006		2			699,444		(400,231	)		383,221

Costs and other deductions
Crude oil and product purchases		40,788		—			518,961		(361,790	)		197,959
Production and manufacturing expenses		7,627		—			33,400		(5,235	)		35,792
Selling, general and administrative expenses		2,871		—			12,482		(670	)		14,683
Depreciation and depletion		1,761		—			12,999		—			14,760
Exploration expenses, including dry holes		251		—			1,893		—			2,144
Interest expense		217		246			4,035		(4,239	)		259
Sales-based taxes		—		—			28,547		—			28,547
Other taxes and duties		29		—			36,089		—			36,118

Total costs and other deductions		53,544		246			648,406		(371,934	)		330,262

Income before income taxes		30,462		(244	)		51,038		(28,297	)		52,959
Income taxes		2		(90	)		21,649		—			21,561

Net income including noncontrolling interests		30,460		(154	)		29,389		(28,297	)		31,398
Net income attributable to noncontrolling interests		—		—			938		—			938

Net income attributable to ExxonMobil	$	30,460	$	(154	)	$	28,451	$	(28,297	)	$	30,460


	Exxon Mobil Corporation Parent Guarantor			SeaRiver Maritime Financial Holdings, Inc.			All Other Subsidiaries		Consolidating and Eliminating Adjustments			Consolidated
	(millions of dollars)
Condensed consolidated statement of income for 12 months ended December 31, 2009
Revenues and other income
Sales and other operating revenue, including sales-based taxes	$	11,352		$	—		$	290,148	$	—		$	301,500
Income from equity affiliates		19,852			7			7,060		(19,776	)		7,143
Other income		813			—			1,130		—			1,943
Intercompany revenue		30,889			4			271,663		(302,556	)		—

Total revenues and other income		62,906			11			570,001		(322,332	)		310,586

Costs and other deductions
Crude oil and product purchases		31,419			—			411,689		(290,302	)		152,806
Production and manufacturing expenses		7,811			—			30,805		(5,589	)		33,027
Selling, general and administrative expenses		2,574			—			12,852		(691	)		14,735
Depreciation and depletion		1,571			—			10,346		—			11,917
Exploration expenses, including dry holes		230			—			1,791		—			2,021
Interest expense		1,200			222			5,126		(6,000	)		548
Sales-based taxes		—			—			25,936		—			25,936
Other taxes and duties		(29	)		—			34,848		—			34,819

Total costs and other deductions		44,776			222			533,393		(302,582	)		275,809

Income before income taxes		18,130			(211	)		36,608		(19,750	)		34,777
Income taxes		(1,150	)		(81	)		16,350		—			15,119

Net income including noncontrolling interests		19,280			(130	)		20,258		(19,750	)		19,658
Net income attributable to noncontrolling interests		—			—			378		—			378

Net income attributable to ExxonMobil	$	19,280		$	(130	)	$	19,880	$	(19,750	)	$	19,280


Condensed consolidated statement of income for 12 months ended December 31, 2008
Revenues and other income
Sales and other operating revenue, including sales-based taxes	$	17,481		$	—		$	442,098	$	—		$	459,579
Income from equity affiliates		45,664			9			11,055		(45,647	)		11,081
Other income		302			—			6,397		—			6,699
Intercompany revenue		48,414			45			442,305		(490,764	)		—

Total revenues and other income		111,861			54			901,855		(536,411	)		477,359

Costs and other deductions
Crude oil and product purchases		48,346			—			669,107		(467,999	)		249,454
Production and manufacturing expenses		8,327			—			35,298		(5,720	)		37,905
Selling, general and administrative expenses		3,349			—			13,364		(840	)		15,873
Depreciation and depletion		1,552			—			10,827		—			12,379
Exploration expenses, including dry holes		192			—			1,259		—			1,451
Interest expense		3,859			207			13,143		(16,536	)		673
Sales-based taxes		—			—			34,508		—			34,508
Other taxes and duties		67			—			41,652		—			41,719

Total costs and other deductions		65,692			207			819,158		(491,095	)		393,962

Income before income taxes		46,169			(153	)		82,697		(45,316	)		83,397
Income taxes		949			(56	)		35,637		—			36,530

Net income including noncontrolling interests		45,220			(97	)		47,060		(45,316	)		46,867
Net income attributable to noncontrolling interests		—			—			1,647		—			1,647

Net income attributable to ExxonMobil	$	45,220		$	(97	)	$	45,413	$	(45,316	)	$	45,220

Condensed consolidated balance sheet


	Exxon Mobil Corporation Parent Guarantor			SeaRiver Maritime Financial Holdings, Inc.			All Other Subsidiaries		Consolidating and Eliminating Adjustments			Consolidated
	(millions of dollars)
Condensed consolidated balance sheet for year ended December 31, 2010
Cash and cash equivalents	$	309		$	—		$	7,516	$	—		$	7,825
Cash and cash equivalents – restricted		371			—			257		—			628
Marketable securities		—			—			2		—			2
Notes and accounts receivable – net		2,104			—			30,346		(166	)		32,284
Inventories		1,457			—			11,519		—			12,976
Other current assets		239			—			5,030		—			5,269

Total current assets		4,480			—			54,670		(166	)		58,984
Investments, advances and long-term receivables		254,781			446			454,489		(674,378	)		35,338
Property, plant and equipment – net		18,830			—			180,718		—			199,548
Other long-term assets		224			12			8,404		—			8,640
Intercompany receivables		18,186			2,457			528,405		(549,048	)		—

Total assets	$	296,501		$	2,915		$	1,226,686	$	(1,223,592	)	$	302,510

Notes and loans payable	$	1,042		$	13		$	1,732	$	—		$	2,787
Accounts payable and accrued liabilities		2,987			—			47,047		—			50,034
Income taxes payable		—			3			9,975		(166	)		9,812

Total current liabilities		4,029			16			58,754		(166	)		62,633
Long-term debt		295			2,389			9,543		—			12,227
Postretirement benefits reserves		9,660			—			9,707		—			19,367
Deferred income tax liabilities		642			107			34,401		—			35,150
Other long-term liabilities		5,632			—			14,822		—			20,454
Intercompany payables		129,404			382			419,262		(549,048	)		—

Total liabilities		149,662			2,894			546,489		(549,214	)		149,831

Earnings reinvested		298,899			(848	)		132,357		(131,509	)		298,899
Other equity		(152,060	)		869			542,000		(542,869	)		(152,060	)

ExxonMobil share of equity		146,839			21			674,357		(674,378	)		146,839
Noncontrolling interests		—			—			5,840		—			5,840

Total equity		146,839			21			680,197		(674,378	)		152,679

Total liabilities and equity	$	296,501		$	2,915		$	1,226,686	$	(1,223,592	)	$	302,510


Condensed consolidated balance sheet for year ended December 31, 2009
Cash and cash equivalents	$	449		$	—		$	10,244	$	—		$	10,693
Marketable securities		—			—			169		—			169
Notes and accounts receivable – net		2,050			—			25,858		(263	)		27,645
Inventories		1,202			—			10,351		—			11,553
Other current assets		313			—			4,862		—			5,175

Total current assets		4,014			—			51,484		(263	)		55,235
Investments, advances and long-term receivables		199,110			449			439,712		(607,606	)		31,665
Property, plant and equipment – net		18,015			—			121,101		—			139,116
Other long-term assets		207			24			7,076		—			7,307
Intercompany receivables		19,637			2,257			442,903		(464,797	)		—

Total assets	$	240,983		$	2,730		$	1,062,276	$	(1,072,666	)	$	233,323

Notes and loans payable	$	43		$	13		$	2,420	$	—		$	2,476
Accounts payable and accrued liabilities		2,779			—			38,496		—			41,275
Income taxes payable		—			2			8,571		(263	)		8,310

Total current liabilities		2,822			15			49,487		(263	)		52,061
Long-term debt		279			2,157			4,693		—			7,129
Postretirement benefits reserves		8,673			—			9,269		—			17,942
Deferred income tax liabilities		818			151			22,179		—			23,148
Other long-term liabilities		5,286			—			12,365		—			17,651
Intercompany payables		112,536			382			351,879		(464,797	)		—

Total liabilities		130,414			2,705			449,872		(465,060	)		117,931

Earnings reinvested		276,937			(694	)		109,603		(108,909	)		276,937
Other equity		(166,368	)		719			497,978		(498,697	)		(166,368	)

ExxonMobil share of equity		110,569			25			607,581		(607,606	)		110,569
Noncontrolling interests		—			—			4,823		—			4,823

Total equity		110,569			25			612,404		(607,606	)		115,392

Total liabilities and equity	$	240,983		$	2,730		$	1,062,276	$	(1,072,666	)	$	233,323

Condensed consolidated statement of cash flows

	Exxon Mobil Corporation Parent Guarantor				SeaRiver Maritime Financial Holdings, Inc				All Other Subsidiaries				Consolidating and Eliminating Adjustments				Consolidated
		(millions of dollars)
Condensed consolidated statement of cash flows for 12 months ended December 31, 2010

Cash provided by/(used in) operating activities		$	35,740			$	63			$	18,307			$	(5,697	)		$	48,413

Cash flows from investing activities
Additions to property, plant and equipment			(2,922	)			—				(23,949	)			—				(26,871	)
Sales of long-term assets			1,484				—				1,777				—				3,261
Decrease/(increase) in restricted cash and cash equivalents			(371	)			—				(257	)			—				(628	)
Net intercompany investing			(13,966	)			(200	)			13,813				353				—
All other investing, net			(672	)			—				706				—				34

Net cash provided by/(used in) investing activities			(16,447	)			(200	)			(7,910	)			353				(24,204	)

Cash flows from financing activities
Additions to short- and long-term debt			—				—				1,741				—				1,741
Reductions in short- and long-term debt			(3	)			(13	)			(8,644	)			—				(8,660	)
Additions/(reductions) in debt with three months or less maturity			997				—				(288	)			—				709
Cash dividends			(8,498	)			—				(5,697	)			5,697				(8,498	)
Common stock acquired			(13,093	)			—				—				—				(13,093	)
Net intercompany financing activity			—				—				202				(202	)			—
All other financing, net			1,164				150				(286	)			(151	)			877

Net cash provided by/(used in) financing activities			(19,433	)			137				(12,972	)			5,344				(26,924	)

Effects of exchange rate changes on cash			—				—				(153	)			—				(153	)

Increase/(decrease) in cash and cash equivalents		$	(140	)		$	—			$	(2,728	)		$	—			$	(2,868	)


Condensed consolidated statement of cash flows for 12 months ended December 31, 2009

Cash provided by/(used in) operating activities		$	27,424			$	72			$	28,024			$	(27,082	)		$	28,438

Cash flows from investing activities
Additions to property, plant and equipment			(2,686	)			—				(19,805	)			—				(22,491	)
Sales of long-term assets			228				—				1,317				—				1,545
Decrease/(increase) in restricted cash and cash equivalents			—				—				—				—				—
Net intercompany investing			(1,826	)			(209	)			1,717				318				—
All other investing, net			—				—				(1,473	)			—				(1,473	)

Net cash provided by/(used in) investing activities			(4,284	)			(209	)			(18,244	)			318				(22,419	)

Cash flows from financing activities
Additions to short- and long-term debt			—				—				1,561				—				1,561
Reductions in short- and long-term debt			(3	)			(13	)			(1,627	)			—				(1,643	)
Additions/(reductions) in debt with three months or less maturity			39				—				(110	)			—				(71	)
Cash dividends			(8,023	)			—				(27,082	)			27,082				(8,023	)
Common stock acquired			(19,703	)			—				—				—				(19,703	)
Net intercompany financing activity			—				—				168				(168	)			—
All other financing, net			988				150				(392	)			(150	)			596

Net cash provided by/(used in) financing activities			(26,702	)			137				(27,482	)			26,764				(27,283	)

Effects of exchange rate changes on cash			—				—				520				—				520

Increase/(decrease) in cash and cash equivalents		$	(3,562	)		$	—			$	(17,182	)		$	—			$	(20,744	)


	Exxon Mobil Corporation Parent Guarantor			SeaRiver Maritime Financial Holdings, Inc.			All Other Subsidiaries			Consolidating and Eliminating Adjustments			Consolidated
	(millions of dollars)
Condensed consolidated statement of cash flows for 12 months ended December 31, 2008

Cash provided by/(used in) operating activities	$	47,823		$	68		$	54,478		$	(42,644	)	$	59,725

Cash flows from investing activities
Additions to property, plant and equipment		(2,154	)		—			(17,164	)		—			(19,318	)
Sales of long-term assets		162			—			5,823			—			5,985
Decrease/(increase) in restricted cash and cash equivalents		—			—			—			—			—
Net intercompany investing		(502	)		(155	)		476			181			—
All other investing, net		—			—			(2,166	)		—			(2,166	)

Net cash provided by/(used in) investing activities		(2,494	)		(155	)		(13,031	)		181			(15,499	)

Cash flows from financing activities
Additions to short- and long-term debt		—			—			1,146			—			1,146
Reductions in short- and long-term debt		(4	)		(13	)		(1,799	)		—			(1,816	)
Additions/(reductions) in debt with three months or less maturity		—			—			143			—			143
Cash dividends		(8,058	)		—			(42,644	)		42,644			(8,058	)
Common stock acquired		(35,734	)		—			—			—			(35,734	)
Net intercompany financing activity		—			—			81			(81	)		—
All other financing, net		1,085			100			(793	)		(100	)		292

Net cash provided by/(used in) financing activities		(42,711	)		87			(43,866	)		42,463			(44,027	)

Effects of exchange rate changes on cash		—			—			(2,743	)		—			(2,743	)

Increase/(decrease) in cash and cash equivalents	$	2,618		$	—		$	(5,162	)	$	—		$	(2,544	)

Incentive Program (Tables)

12 Months Ended

Dec. 31, 2010

Summary of restricted stock and units outstanding


	2010
Restricted stock and units outstanding	Shares			Weighted Average Grant-Date Fair Value per Share
	(thousands)
Issued and outstanding at January 1		43,503		$	67.52
2009 award issued in 2010		10,132		$	75.40
Merger-related granted and converted XTO awards		4,206		$	59.31
Vested		(10,377	)	$	61.72
Forfeited		(158	)	$	67.91

Issued and outstanding at December 31		47,306		$	69.74

Grant value of restricted stock and units


Value of restricted stock and units	2010		2009		2008
Grant price	$	66.07	$	75.40	$	78.24
Value at date of grant:		(millions of dollars)
Restricted stock and units settled in stock	$	672	$	711	$	735
Merger-related granted and converted XTO awards		250		—		—
Units settled in cash		60		53		56

Total value	$	982	$	764	$	791

Converted performance stock awards


	Dec, 31, 2010
Performance stock awards	Shares
	(thousands)
Vesting Price:
$108.49		38
$119.76		38

Summary of stock options outstanding


	2010
Stock options	Shares			Avg. Exercise Price		Weighted Average Remaining Contractual Term
Outstanding at January 1		41,473		$	40.92
Merger-related converted XTO awards		12,393		$	55.15
Exercised		(24,305	)	$	43.62
Forfeited		(52	)	$	45.91

Outstanding at December 31		29,509		$	44.65		2.0 Years

Exercisable at December 31		28,935		$	43.94		1.9 Years

Fair values used in determining XTO merger-related stock based awards


Weighted average expected term			2.5 years
Range of risk-free interest rates			0.1% - 2.6%

Weighted average risk-free interest rates			0.9%
Dividend yield			3.0%

Weighted average volatility			28.5%
Range of volatility			22.5% - 33.6%

Litigation and Other Contingencies (Tables)

12 Months Ended

Dec. 31, 2010

Unconditional purchase obligations

Schedule of guarantees


	Dec. 31, 2010
	Equity Company Obligations		Other Third-Party Obligations		Total
	(millions of dollars)

Guarantees	$	5,290	$	3,481	$	8,771

Payments Due by Period
	2011		2012- 2015		2016 and Beyond		Total
	(millions of dollars)

Unconditional purchase obligations (1)	$	287	$	748	$	487	$	1,522

(1)

Pension and Other Postretirement Benefits (Tables)

12 Months Ended

Dec. 31, 2010

Dec. 31, 2009

Change in benefit obligation of pension and other postretirement benefits

Pension Benefits												Other Postretirement Benefits
	U.S.						Non-U.S.					Other Postretirement Benefits
	2010			2009			2010			2009			2010			2009
	(percent)
Weighted-average assumptions used to determine benefit obligations at December 31
Discount rate		5.50			6. 00			4.80			5.20			5.50			6.00
Long-term rate of compensation increase		5.00			5.00			5.20			5.00			5.00			5.00

	(millions of dollars)
Change in benefit obligation
Benefit obligation at January 1	$	13,981		$	13,272		$	23,344		$	19,990		$	6,748		$	6,633
Service cost		468			438			480			421			101			94
Interest cost		798			809			1,175			1,121			395			408
Actuarial loss/(gain)		553			1,126			1,672			1,280			277			(49	)
Benefits paid (1) (2)		(873	)		(1,665	)		(1,281	)		(1,174	)		(394	)		(480	)
Foreign exchange rate changes		—			—			169			1,676			26			60
Plan amendments, other		80			1			163			30			178			82

Benefit obligation at December 31	$	15,007		$	13,981		$	25,722		$	23,344		$	7,331		$	6,748


Accumulated benefit obligation at December 31	$	12,764		$	11,615		$	22,958		$	20,909		$	—		$	—

(1)

Benefit payments for funded and unfunded plans.

(2)

For 2010 and 2009, other postretirement benefits paid are net of $15 million and $28 million of Medicare subsidy receipts, respectively.

Change in plan assets of pension and other postretirement benefits

Pension Benefits												Other Postretirement Benefits
	U.S.						Non-U.S.					Other Postretirement Benefits
	2010			2009			2010			2009			2010			2009
	(millions of dollars)
Change in plan assets
Fair value at January 1	$	10,277		$	6,634		$	15,401		$	11,260		$	514		$	443
Actual return on plan assets		1,235			2,013			1,482			2,201			63			93
Foreign exchange rate changes		—			—			99			1,300			—			—
Company contribution		—			3,070			1,184			1,456			38			36
Benefits paid (1)		(677	)		(1,440	)		(873	)		(795	)		(59	)		(57	)
Other		—			—			(528	)		(21	)		2			(1	)

Fair value at December 31	$	10,835		$	10,277		$	16,765		$	15,401		$	558		$	514

(1)

Benefit payments for funded plans.

Summary of assets in excess of/(less than) benefit obligation


	Pension Benefits
	U.S.						Non-U.S.
	2010			2009			2010			2009
	(millions of dollars)
Assets in excess of/(less than) benefit obligation
Balance at December 31
Funded plans	$	(2,349	)	$	(1,940	)	$	(2,769	)	$	(2,085	)
Unfunded plans		(1,823	)		(1,764	)		(6,188	)		(5,858	)

Total	$	(4,172	)	$	(3,704	)	$	(8,957	)	$	(7,943	)

Amounts recorded in balance sheet and other comprehensive income

Pension Benefits												Other Postretirement Benefits
	U.S.						Non-U.S.					Other Postretirement Benefits
	2010			2009			2010			2009			2010			2009
	(millions of dollars)
Assets in excess of/(less than) benefit obligation
Balance at December 31 (1)	$	(4,172	)	$	(3,704	)	$	(8,957	)	$	(7,943	)	$	(6,773	)	$	(6,234	)


Amounts recorded in the consolidated balance sheet consist of:
Other assets	$	1		$	1		$	400		$	961		$	—		$	—
Current liabilities		(257	)		(235	)		(336	)		(348	)		(343	)		(318	)
Postretirement benefits reserves		(3,916	)		(3,470	)		(9,021	)		(8,556	)		(6,430	)		(5,916	)

Total recorded	$	(4,172	)	$	(3,704	)	$	(8,957	)	$	(7,943	)	$	(6,773	)	$	(6,234	)


Amounts recorded in accumulated other comprehensive income consist of:
Net actuarial loss/(gain)	$	5,028		$	5,830		$	7,795		$	7,036		$	1,985		$	1,878
Prior service cost		83			5			674			622			154			181

Total recorded in accumulated other comprehensive income	$	5,111		$	5,835		$	8,469		$	7,658		$	2,139		$	2,059

(1)

Fair value of assets less benefit obligation shown on the preceding page.

Schedule of assumptions, components of benefit cost and amounts recorded in accumulated other comprehensive income for pension and other postretirement benefits

	Pension Benefits																		Other Postretirement
	U.S.									Non-U.S.									Benefits
	2010			2009			2008			2010			2009			2008			2010			2009			2008
	(percent)
Weighted-average assumptions used to determine net periodic benefit cost for years ended December 31
Discount rate		6.00			6.25			6.25			5.20			5.50			5.40			6.00			6.25			6.25
Long-term rate of return on funded assets		7.50			8.00			9.00			6.70			7.30			7.50			7.50			8.00			9.00
Long-term rate of compensation increase		5.00			5.00			5.00			5.00			4.70			4.50			5.00			5.00			5.00

	(millions of dollars)
Components of net periodic benefit cost
Service cost	$	468		$	438		$	378		$	480		$	421		$	434		$	101		$	94		$	100
Interest cost		798			809			729			1,175			1,121			1,152			395			408			414
Expected return on plan assets		(726	)		(656	)		(915	)		(1,010	)		(886	)		(1,200	)		(37	)		(35	)		(59	)
Amortization of actuarial loss/(gain)		525			694			239			554			648			318			147			176			197
Amortization of prior service cost		2			—			(2	)		84			79			93			52			69			76
Net pension enhancement and curtailment/settlement expense		321			485			174			9			2			32			—			—			—

Net periodic benefit cost	$	1,388		$	1,770		$	603		$	1,292		$	1,385		$	829		$	658		$	712		$	728


Changes in amounts recorded in accumulated other comprehensive income:
Net actuarial loss/(gain)	$	44		$	(231	)	$	5,275		$	1,202		$	(33	)	$	4,837		$	251		$	(107	)	$	13
Amortization of actuarial (loss)/gain		(846	)		(1,179	)		(413	)		(563	)		(650	)		(350	)		(147	)		(176	)		(197	)
Prior service cost/(credit)		80			—			—			160			69			16			26			—			—
Amortization of prior service (cost)		(2	)		—			2			(84	)		(79	)		(93	)		(52	)		(69	)		(76	)
Foreign exchange rate changes		—			—			—			96			608			(997	)		2			2			(3	)

Total recorded in other comprehensive income		(724	)		(1,410	)		4,864			811			(85	)		3,413			80			(350	)		(263	)
Total recorded in net periodic benefit cost and other comprehensive income, before tax	$	664		$	360		$	5,467		$	2,103		$	1,300		$	4,242		$	738		$	362		$	465

Summary of change in accumulated other comprehensive income


	Total Pension and Other Postretirement Benefits
	2010			2009			2008
	(millions of dollars)
(Charge)/credit to other comprehensive income, before tax
U.S. pension	$	724		$	1,410		$	(4,864	)
Non-U.S. pension		(811	)		85			(3,413	)
Other postretirement benefits		(80	)		350			263

Total (charge)/credit to other comprehensive income, before tax		(167	)		1,845			(8,014	)
(Charge)/credit to income tax (see note 18)		35			(591	)		2,723
(Charge)/credit to investment in equity companies		11			(133	)		(27	)

(Charge)/credit to other comprehensive income including noncontrolling interests, after tax	$	(121	)	$	1,121		$	(5,318	)
Charge/(credit) to equity of noncontrolling interests		95			93			224

(Charge)/credit to other comprehensive income attributable to ExxonMobil	$	(26	)	$	1,214		$	(5,094	)

Fair value of the benefit plan assets (pension)

U.S. Pension											Non-U.S. Pension
	Fair Value Measurement at December 31, 2010, Using:											Fair Value Measurement at December 31, 2010, Using:
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total
	(millions of dollars)											(millions of dollars)
Asset category:
Equity securities
U.S.	$	—	$	2,648	⁽¹⁾	$	—		$	2,648		$	—		$	2,443	⁽¹⁾	$	—		$	2,443
Non-U.S.		—		3,530	⁽¹⁾		—			3,530			228	⁽²⁾		6,502	⁽¹⁾		—			6,730
Private equity		—		—			408	⁽³⁾		408			—			—			315	⁽³⁾		315
Debt securities
Corporate		—		1,152	⁽⁴⁾		—			1,152			2	⁽⁵⁾		1,629	⁽⁴⁾		—			1,631
Government		—		2,847	⁽⁴⁾		—			2,847			146	⁽⁵⁾		4,709	⁽⁴⁾		—			4,855
Asset-backed		—		31	⁽⁴⁾		—			31			—			98	⁽⁴⁾		—			98
Private mortgages		—		—			128	⁽⁶⁾		128			—			—			4	⁽⁶⁾		4
Real estate funds		—		—			—			—			—			—			417	⁽⁷⁾		417
Cash		68		—			—			68			63			51	⁽⁸⁾		—			114

Total at fair value	$	68	$	10,208		$	536		$	10,812		$	439		$	15,432		$	736		$	16,607
Insurance contracts at contract value										23												158

Total plan assets									$	10,835											$	16,765

(1)

(2)

For non-U.S. equity securities held in separate accounts, fair value is based on observable quoted prices on active exchanges.

(3)

For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings.

(4)

For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions.

(5)

For corporate and government debt securities that are traded on active exchanges, fair value is based on observable quoted prices.

(6)

For private mortgages, fair value is based on proprietary credit spread matrices developed using market data and monthly surveys of active mortgage bankers.

(7)

For real estate funds, fair value is based on appraised values developed using comparable market transactions.

(8)

For cash balances that are subject to withdrawal penalties or other adjustments, the fair value is treated as a Level 2 input.

U.S. Pension											Non-U.S. Pension
	Fair Value Measurement at December 31, 2009, Using:											Fair Value Measurement at December 31, 2009, Using:
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total
	(millions of dollars)											(millions of dollars)
Asset category:
Equity securities
U.S.	$	—	$	2,503	⁽¹⁾	$	—		$	2,503		$	—		$	2,244	⁽¹⁾	$	—		$	2,244
Non-U.S.		—		3,341	⁽¹⁾		—			3,341			227	⁽²⁾		5,946	⁽¹⁾		—			6,173
Private equity		—		—			349	⁽³⁾		349			—			—			239	⁽³⁾		239
Debt securities
Corporate		—		1,040	⁽⁴⁾		—			1,040			2	⁽⁵⁾		1,637	⁽⁴⁾		—			1,639
Government		—		2,570	⁽⁴⁾		—			2,570			70	⁽⁵⁾		4,217	⁽⁴⁾		—			4,287
Asset-backed		—		30	⁽⁴⁾		—			30			—			119	⁽⁴⁾		—			119
Private mortgages		—		—			280	⁽⁶⁾		280			—			—			5	⁽⁶⁾		5
Real estate funds		—		—			—			—			—			—			413	⁽⁷⁾		413
Cash		140		—			—			140			79			55	⁽⁸⁾		—			134

Total at fair value	$	140	$	9,484		$	629		$	10,253		$	378		$	14,218		$	657		$	15,253
Insurance contracts at contract value										24												148

Total plan assets									$	10,277											$	15,401

(1)

(2)

For non-U.S. equity securities held in separate accounts, fair value is based on observable quoted prices on active exchanges.

(3)

For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings.

(4)

For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions.

(5)

For corporate and government debt securities that are traded on active exchanges, fair value is based on observable quoted prices.

(6)

For private mortgages, fair value is based on proprietary credit spread matrices developed using market data and monthly surveys of active mortgage bankers.

(7)

For real estate funds, fair value is based on appraised values developed using comparable market transactions.

(8)

For cash balances that are subject to withdrawal penalties or other adjustments, the fair value is treated as a Level 2 input.

Fair value of the benefit plan assets (other postretirement)

Other Postretirement
	Fair Value Measurement at December 31, 2010, Using:
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total
	(millions of dollars)
Asset category:
Equity securities
U.S.	$	—	$	180	⁽¹⁾	$	—		$	180
Non-U.S.		—		191	⁽¹⁾		—			191
Private equity		—		—			5	⁽²⁾		5
Debt securities
Corporate		—		49	⁽³⁾		—			49
Government		—		117	⁽³⁾		—			117
Asset-backed		—		13	⁽³⁾		—			13
Private mortgages		—		—			2	⁽⁴⁾		2
Cash		1		—			—			1

Total at fair value	$	1	$	550		$	7		$	558

(1)

(2)

For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings.

(3)

For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions.

(4)

For private mortgages, fair value is based on proprietary credit spread matrices developed using market data and monthly surveys of active mortgage bankers.

Other Postretirement
	Fair Value Measurement at December 31, 2009, Using:
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total
	(millions of dollars)
Asset category:
Equity securities
U.S.	$	—	$	166	⁽¹⁾	$	—		$	166
Non-U.S.		—		181	⁽¹⁾		—			181
Private equity		—		—			4	⁽²⁾		4
Debt securities
Corporate		—		51	⁽³⁾		—			51
Government		—		95	⁽³⁾		—			95
Asset-backed		—		11	⁽³⁾		—			11
Private mortgages		—		—			3	⁽⁴⁾		3
Cash		3		—			—			3

Total at fair value	$	3	$	504		$	7		$	514

(1)

(2)

For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings.

(3)

For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions.

(4)

For private mortgages, fair value is based on proprietary credit spread matrices developed using market data and monthly surveys of active mortgage bankers.

Change in fair value of level 3 assets


	2010
	Pension														Other Postretirement
	U.S.					Non U.S.
	Private Equity		Private Mortgages			Private Equity			Private Mortgages			Real Estate			Private Equity		Private Mortgages
	(millions of dollars)
Fair value at January 1	$	349	$	280		$	239		$	5		$	413		$	4	$	3

Net realized gains/(losses)		—		36			(1	)		(1	)		—			—		1
Net unrealized gains/(losses)		47		(3	)		26			1			(4	)		1		—
Net purchases/(sales)		12		(185	)		51			(1	)		8			—		(2	)

Fair value at December 31	$	408	$	128		$	315		$	4		$	417		$	5	$	2


	2009
	Pension														Other Postretirement
	U.S.						Non U.S.
	Private Equity			Private Mortgages			Private Equity			Private Mortgages		Real Estate			Private Equity		Private Mortgages
	(millions of dollars)
Fair value at January 1	$	346		$	476		$	238		$	5	$	409		$	4	$	6

Net realized gains/(losses)		4			11			(10	)		—		(7	)		—		—
Net unrealized gains/(losses)		(35	)		7			(35	)		—		(11	)		—		—
Net purchases/(sales)		34			(214	)		46			—		22			—		(3	)

Fair value at December 31	$	349		$	280		$	239		$	5	$	413		$	4	$	3

Pension plans with accumulated benefit obligation in excess of plan assets

Pension Benefits
	U.S.				Non-U.S.
	2010		2009		2010		2009
	(millions of dollars)
For funded pension plans with an accumulated benefit obligation in excess of plan assets:
Projected benefit obligation	$	13,184	$	12,217	$	9,865	$	13,152
Accumulated benefit obligation		11,383		10,312		9,074		12,260
Fair value of plan assets		10,834		10,276		7,131		10,447

For unfunded pension plans:
Projected benefit obligation	$	1,823	$	1,764	$	6,188	$	5,858
Accumulated benefit obligation		1,381		1,303		5,413		5,180

	Pension Benefits				Other Postretirement
	U.S.		Non-U.S.		Benefits
	(millions of dollars)
Estimated 2011 amortization from accumulated other comprehensive income:
Net actuarial loss/(gain) (1)	$	835	$	615		$ 159
Prior service cost (2)		9		97		35

(1)

The Corporation amortizes the net balance of actuarial losses/(gains) as a component of net periodic benefit cost over the average remaining service period of active plan participants.

(2)

The Corporation amortizes prior service cost on a straight-line basis as permitted under authoritative guidance for defined benefit pension and other postretirement benefit plans.

Expected contribution pension benefits and other postretirement benefits


	Pension Benefits				Other Postretirement Benefits
	U.S.		Non-U.S.		Gross		Medicare Subsidy Receipt
	(millions of dollars)
Contributions expected in 2011	$	270	$	1,130	$	—	$	—

Benefit payments expected in:
2011		1,454		1,299		440		23
2012		1,483		1,281		456		25
2013		1,512		1,316		474		26
2014		1,451		1,362		489		28
2015		1,392		1,393		502		29
2016 - 2020		6,079		8,325		2,662		163

Disclosures about Segments and Related Information (Tables)

12 Months Ended

Dec. 31, 2010

Disclosures about segments and related information


	Upstream				Downstream						Chemical					Corporate and Financing			Corporate Total
	U.S.		Non-U.S.		U.S.			Non-U.S.			U.S.		Non-U.S.			Corporate and Financing			Corporate Total
As of December 31, 2010		(millions of dollars)
Earnings after income tax	$	4,272	$	19,825	$	770		$	2,797		$	2,422	$	2,491		$	(2,117	)	$	30,460
Earnings of equity companies included above		1,261		8,415		23			225			171		1,163			(581	)		10,677
Sales and other operating revenue (1)		8,895		26,046		93,599			206,042			13,402		22,119			22			370,125
Intersegment revenue		8,102		39,066		13,546			52,697			9,694		8,421			282			—
Depreciation and depletion expense		3,506		7,574		681			1,565			421		432			581			14,760
Interest revenue		—		—		—			—			—		—			118			118
Interest expense		20		25		1			19			1		4			189			259
Income taxes		2,219		18,627		360			560			736		347			(1,288	)		21,561
Additions to property, plant and equipment		52,300		16,937		888			1,332			247		1,733			719			74,156
Investments in equity companies		2,636		9,625		254			1,240			285		3,586			(197	)		17,429
Total assets		76,725		115,646		18,378			47,402			7,148		19,087			18,124			302,510

As of December 31, 2009
Earnings after income tax	$	2,893	$	14,214	$	(153	)	$	1,934		$	769	$	1,540		$	(1,917	)	$	19,280
Earnings of equity companies included above		1,216		5,269		(102	)		188			164		906			(498	)		7,143
Sales and other operating revenue (1)		3,406		21,355		76,467			173,404			9,962		16,885			21			301,500
Intersegment revenue		6,718		32,982		10,168			39,190			7,185		6,947			284			—
Depreciation and depletion expense		1,768		6,376		687			1,665			400		457			564			11,917
Interest revenue		—		—		—			—			—		—			179			179
Interest expense		38		27		10			18			4		1			450			548
Income taxes		1,451		15,183		(164	)		(22	)		281		(182	)		(1,428	)		15,119
Additions to property, plant and equipment		2,973		13,307		1,449			1,447			294		2,553			468			22,491
Investments in equity companies		2,440		8,864		323			1,190			259		2,873			(207	)		15,742
Total assets		24,940		102,372		17,493			45,098			7,044		17,117			19,259			233,323

As of December 31, 2008
Earnings after income tax	$	6,243	$	29,159	$	1,649		$	6,502		$	724	$	2,233		$	(1,290	)	$	45,220
Earnings of equity companies included above		1,954		7,597		(2	)		518			105		1,411			(502	)		11,081
Sales and other operating revenue (1)		6,767		32,346		116,701			265,359			14,136		24,252			18			459,579
Intersegment revenue		9,617		55,069		16,225			65,723			9,925		9,749			273			—
Depreciation and depletion expense		1,391		7,266		656			1,672			410		422			562			12,379
Interest revenue		—		—		—			—			—		—			1,400			1,400
Interest expense		47		63		9			28			3		4			519			673
Income taxes		3,451		30,654		728			1,990			177		10			(480	)		36,530
Additions to property, plant and equipment		2,699		10,545		1,550			1,552			413		1,987			572			19,318
Investments in equity companies		2,248		7,787		456			1,382			241		2,384			(40	)		14,458
Total assets		23,056		83,750		16,328			42,044			6,856		13,300			42,718			228,052

Schedule of long-lived assets by geographic regions


Geographic Sales and other operating revenue (1)	2010		2009		2008
	(millions of dollars)
United States	$	115,906	$	89,847	$	137,615
Non-U.S.		254,219		211,653		321,964

Total	$	370,125	$	301,500	$	459,579


Significant non-U.S. revenue sources include:
Canada	$	27,243	$	21,151	$	33,677
Japan		27,143		22,054		30,126
United Kingdom		24,637		20,293		29,764
Belgium		21,139		16,857		25,399
Germany		14,301		14,839		20,591
Italy		14,132		12,997		17,953
France		13,920		12,042		18,530
Singapore		11,088		8,400		11,059

Long-lived assets	2010		2009		2008
	(millions of dollars)
United States	$	86,021	$	37,138	$	35,548
Non-U.S.		113,527		101,978		85,798

Total	$	199,548	$	139,116	$	121,346


Significant non-U.S. long-lived assets include:
Canada	$	20,879	$	15,919	$	12,018
Nigeria		11,429		11,046		9,227
Singapore		8,610		7,238		5,113
Angola		8,570		7,320		6,129
Norway		6,988		7,251		5,856
Australia		6,570		4,247		2,857
United Kingdom		6,177		7,609		5,778
Kazakhstan		5,938		4,748		3,535

(1)

Sales and other operating revenue includes sales-based taxes of $28,547 million for 2010, $25,936 million for 2009 and $34,508 million for 2008.

Income, Sales-Based and Other Taxes (Tables)

12 Months Ended

Dec. 31, 2010

Schedule of income, sales-based and other taxes


	2010								2009									2008
	U.S.		Non-U.S.			Total			U.S.			Non-U.S.			Total			U.S.		Non-U.S.		Total
Income taxes		(millions of dollars)
Federal and non-U.S.
Current	$	1,224	$	21,093		$	22,317		$	(838	)	$	15,830		$	14,992		$	3,005	$	31,377	$	34,382
Deferred – net		49		(1,191	)		(1,142	)		650			(665	)		(15	)		168		1,289		1,457
U.S. tax on non-U.S. operations		46		—			46			32			—			32			230		—		230

Total federal and non-U.S.		1,319		19,902			21,221			(156	)		15,165			15,009			3,403		32,666		36,069
State		340		—			340			110			—			110			461		—		461

Total income taxes		1,659		19,902			21,561			(46	)		15,165			15,119			3,864		32,666		36,530
Sales-based taxes		6,182		22,365			28,547			6,271			19,665			25,936			6,646		27,862		34,508
All other taxes and duties
Other taxes and duties		776		35,342			36,118			581			34,238			34,819			1,663		40,056		41,719
Included in production and manufacturing expenses		1,001		1,237			2,238			699			1,318			2,017			915		1,720		2,635
Included in SG&A expenses		201		570			771			197			538			735			209		660		869

Total other taxes and duties		1,978		37,149			39,127			1,477			36,094			37,571			2,787		42,436		45,223

Total	$	9,819	$	79,416		$	89,235		$	7,702		$	70,924		$	78,626		$	13,297	$	102,964	$	116,261

Income taxes (charged)/credited directly to equity


	2010			2009			2008
	(millions of dollars)
Cumulative foreign exchange translation adjustment	$	(42	)	$	(247	)	$	360
Postretirement benefits reserves adjustment:
Net actuarial loss/(gain)		553			(94	)		3,361
Amortization of actuarial loss/(gain)		(609	)		(649	)		(317	)
Prior service cost		92			20			4
Amortization of prior service cost		(45	)		(43	)		(51	)
Foreign exchange rate changes		44			175			(274	)

Total postretirement benefits reserves adjustment		35			(591	)		2,723
Other components of equity		246			140			315

Reconciliation between income tax expense and a theoretical U.S. tax


	2010			2009			2008
	(millions of dollars)
Income before income taxes
United States	$	7,711		$	2,576		$	10,152
Non-U.S.		45,248			32,201			73,245

Total	$	52,959		$	34,777		$	83,397

Theoretical tax	$	18,536		$	12,172		$	29,189
Effect of equity method of accounting		(3,737	)		(2,500	)		(3,878	)
Non-U.S. taxes in excess of theoretical U.S. tax		7,293			5,948			10,188
U.S. tax on non-U.S. operations		46			32			230
State taxes, net of federal tax benefit		221			72			300
Other U.S.		(798	)		(605	)		501

Total income tax expense	$	21,561		$	15,119		$	36,530


Effective tax rate calculation
Income taxes	$	21,561		$	15,119		$	36,530
ExxonMobil share of equity company income taxes		4,058			2,489			4,001

Total income taxes		25,619			17,608			40,531
Net income including noncontrolling interests		31,398			19,658			46,867

Total income before taxes	$	57,017		$	37,266		$	87,398


Effective income tax rate		45	%		47	%		46	%

Deferred tax liabilities/(assets)


Tax effects of temporary differences for:	2010			2009
	(millions of dollars)
Property, plant and equipment	$	42,657		$	29,931
Other liabilities		4,278			4,102

Total deferred tax liabilities	$	46,935		$	34,033


Pension and other postretirement benefits	$	(5,634	)	$	(5,442	)
Asset retirement obligations		(4,461	)		(3,978	)
Tax loss carryforwards		(3,243	)		(3,693	)
Other assets		(6,070	)		(4,700	)

Total deferred tax assets	$	(19,408	)	$	(17,813	)

Asset valuation allowances		1,183			1,495

Net deferred tax liabilities	$	28,710		$	17,715

Deferred income tax (assets) and liabilities by balance sheet classification


Balance sheet classification	2010			2009
	(millions of dollars)
Other current assets	$	(3,359	)	$	(3,322	)
Other assets, including intangibles, net		(3,527	)		(2,263	)
Accounts payable and accrued liabilities		446			152
Deferred income tax liabilities		35,150			23,148

Net deferred tax liabilities	$	28,710		$	17,715

Unrecognized tax benefits


Gross unrecognized tax benefits	2010			2009			2008
	(millions of dollars)
Balance at January 1	$	4,725		$	4,976		$	5,232
Additions based on current year's tax positions		830			547			656
Additions for prior years' tax positions		620			262			294
Reductions for prior years' tax positions		(505	)		(594	)		(328	)
Reductions due to lapse of the statute of limitations		(534	)		—			(27	)
Settlements with tax authorities		(999	)		(592	)		(681	)
Foreign exchange effects/other		11			126			(170	)

Balance at December 31	$	4,148		$	4,725		$	4,976

Remaining tax years subject to examination by major tax jurisdiction


Country of Operation		Open Tax Years
Abu Dhabi		2000 - 2010
Angola		2007 - 2010
Australia		2000 - 2010
Canada		1994 - 2010
Equatorial Guinea		2005 - 2010
Germany		1999 - 2010
Japan		2003 - 2010
Malaysia		2004 - 2010
Nigeria		1998 - 2010
Norway		2000 - 2010
United Kingdom		2004 - 2010
United States:		1991 - 1996
		1998 - 2000
		2004 - 2010

Acquisition of XTO Energy Inc. (Tables)

12 Months Ended

Dec. 31, 2010

Components of Consideration Transferred in Merger of XTO Energy Inc.


	(millions of dollars)

Consideration attributable to stock issued (1) (2)	$	24,480
Consideration attributable to converted stock options (2)		179

Total consideration transferred	$	24,659

(1)

(2)	The portion of the fair value of XTO converted stock-based awards attributable to pre-merger employee service was part of consideration. The remaining fair value of the awards will be recognized in future periods over the requisite service period.

Recording of Assets Acquired and Liabilities Assumed in Merger of XTO Energy Inc.


	(millions of dollars)
Cash and cash equivalents	$	47
Notes and accounts receivable		925
Inventories		170
Other current assets (1)		911
Investments, advances and long-term receivables		52
Property, plant and equipment (2)		47,300
Identifiable intangible assets (3)		493
Goodwill (4)		39
Other assets (1)		75

Total assets acquired	$	50,012


Notes and loans payable (5)	$	1,026
Accounts payable and accrued liabilities (1) (6)		1,788
Income taxes payable		(199	)
Long-term debt (5)		10,574
Postretirement benefits reserves		65
Deferred income tax liabilities (6)		11,204
Other long-term obligations		895

Total liabilities assumed	$	25,353

Net assets acquired	$	24,659

(1)	Derivatives were measured using Level 1 inputs for derivatives that are traded directly on the NYMEX and Level 2 inputs for derivatives that are determined by either market prices on an active market for similar assets or by prices quoted by a broker or other market-corroborated prices.

(2)

(3)	Identifiable intangible assets and other assets were measured using a combination of an income approach and a market approach (Level 3). Identifiable intangible assets will be amortized over 20 years.

(4)

(5)	Long-term debt was recognized mainly at market rates at closing (Level 1).

(6)	Deferred income taxes reflect the temporary differences between the amount of assets and liabilities recognized for financial reporting purposes and such amounts recognized for tax purposes.

Revenues and Earnings for XTO Energy Inc.


	Acquisition Date Through December 31, 2010
	(millions of dollars)
Revenues	$	4,448

Upstream earnings	$	262

Pro Forma Information for the Corporation as if Merger of XTO Energy Inc. Had Occurred at Beginning of Each Year Presented


	2010		2009
	(millions of dollars, except per share amounts)

Revenues	$	373,273	$	307,456

Net income attributable to ExxonMobil	$	30,668	$	19,672

Earnings per common share	$	6.03	$	3.75

Earnings per common share – assuming dilution	$	6.01	$	3.74

Summary of Accounting Policies (Narrative) (Details)	12 Months Ended
Summary of Accounting Policies (Narrative) (Details)	Dec. 31, 2010
Statement [Line Items]
Consolidated financial statements, minimum voting rights of subsidiaries held by the Corporation	50 percent

Miscellaneous Financial Information (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Research and development costs	$ 1,012	$ 1,050	$ 847
Foreign currency transaction gain (loss), before tax	(251)	54	54
Gains on combined effects of LIFO inventory accumulations and draw-downs	317	207	$ 341
Replacement cost of inventories estimated to exceed LIFO carrying values	21,300	$ 17,100
Total cash and cash equivalents	8,453
Restricted funds	628
ExxonMobil Corporation Parent Guarantor [Member]
Statement [Line Items]
Restricted funds	$ 371

Miscellaneous Financial Information (Crude Oil, Products and Merchandise) (Details) - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009
Statement [Line Items]
Petroleum products	$ 3,500	$ 3,200
Crude oil	3,800	3,200
Chemical products	2,100	2,000
Gas/other	500	300
Total	$ 9,852	$ 8,718

Cash Flow Information (Cash Payments) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Cash payments for interest	$ 703	$ 820	$ 650
Cash payments for income taxes	$ 18,941	$ 15,427	$ 33,941

Additional Working Capital Information (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009
Statement [Line Items]
Trade reserves	$ 152	$ 198
Other reserves	34	$ 31
Unused credit lines for short-term financing	5,600
Commercial paper programs under terms negotiated	$ 2,800
The weighted-average interest rate on short-term borrowings outstanding	1.20%	3.60%

Additional Working Capital Information (Schedule of Notes, Accounts Receivable and Payable, Loans Payable, Accrued Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009
Additional Working Capital Information
Trade, less reserves of $152 million and $198 million	$ 25,439	$ 22,186
Other, less reserves of $34 million and $31 million	6,845	5,459
Total	32,284	27,645
Bank loans	532	1,043
Commercial paper	1,346	201
Long-term debt due within one year	345	348
Other	564	884
Total	2,787	2,476
Trade payables	30,780	24,236
Payables to equity companies	5,450	4,979
Accrued taxes other than income taxes	6,778	5,921
Other	7,026	6,139
Total	$ 50,034	$ 41,275

Equity Company Information (Narrative) (Details)	12 Months Ended
Equity Company Information (Narrative) (Details)	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Share of equity company sales revenues from consolidated companies sales revenues, as a percentage	18.00%	19.00%	21.00%

Equity Company Information (Schedule of Equity Company Financial Summary) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Income before income taxes	$ 52,959	$ 34,777	$ 83,397
Investments (Companies carried at equity in underlying assets)	17,429	15,742
ExxonMobil Share of Equity [Member]
Statement [Line Items]
Total revenues	48,355	36,570	49,999
Income before income taxes	14,735	9,632	15,082
Income taxes	4,058	2,489	4,001
Income from equity affiliates	10,677	7,143	11,081
Current assets	15,860	12,843	9,920
Long-term assets	29,805	27,983	28,339
Total assets	45,665	40,826	38,259
Current liabilities	10,260	8,085	8,707
Long-term liabilities	17,976	16,999	15,094
Investments (Companies carried at equity in underlying assets)	17,429	15,742	14,458
Total Equity Company [Member]
Statement [Line Items]
Total revenues	153,020	112,153	148,477
Income before income taxes	48,075	28,472	42,588
Income taxes	13,962	7,775	12,020
Income from equity affiliates	34,113	20,697	30,568
Current assets	48,573	37,376	29,358
Long-term assets	90,646	88,153	87,442
Total assets	139,219	125,529	116,800
Current liabilities	33,160	24,854	26,221
Long-term liabilities	59,596	57,384	50,895
Investments (Companies carried at equity in underlying assets)	$ 46,463	$ 43,291	$ 39,684

Equity Company Information (Schedule Of Corporation's Percentage Ownership Interest) (Details)	Dec. 31, 2010
Upstream [Member] \| Aera Energy LLC [Member]
Statement [Line Items]
Percentage ownership interest	48.00%
Upstream [Member] \| BEB Erdgas und Erdoel GmbH [Member]
Statement [Line Items]
Percentage ownership interest	50.00%
Upstream [Member] \| Cameroon Oil Transportation Company S.A. [Member]
Statement [Line Items]
Percentage ownership interest	41.00%
Upstream [Member] \| Castle Peak Power Company Limited [Member]
Statement [Line Items]
Percentage ownership interest	60.00%
Upstream [Member] \| Golden Pass LNG Terminal LLC [Member]
Statement [Line Items]
Percentage ownership interest	18.00%
Upstream [Member] \| Nederlandse Aardolie Maatschappij B.V. [Member]
Statement [Line Items]
Percentage ownership interest	50.00%
Upstream [Member] \| Qatar Liquefied Gas Company Limited [Member]
Statement [Line Items]
Percentage ownership interest	10.00%
Upstream [Member] \| Qatar Liquefied Gas Company Limited 2 [Member]
Statement [Line Items]
Percentage ownership interest	24.00%
Upstream [Member] \| Ras Laffan Liquefied Natural Gas Company Limited [Member]
Statement [Line Items]
Percentage ownership interest	25.00%
Upstream [Member] \| Ras Laffan Liquefied Natural Gas Company Limited II [Member]
Statement [Line Items]
Percentage ownership interest	31.00%
Upstream [Member] \| Ras Laffan Liquefied Natural Gas Company Limited (3) [Member]
Statement [Line Items]
Percentage ownership interest	30.00%
Upstream [Member] \| South Hook LNG Terminal Company Limited [Member]
Statement [Line Items]
Percentage ownership interest	24.00%
Upstream [Member] \| Tengizchevroil, LLP [Member]
Statement [Line Items]
Percentage ownership interest	25.00%
Upstream [Member] \| Terminale GNL Adriatico S.r.l. [Member]
Statement [Line Items]
Percentage ownership interest	69.00%
Downstream [Member] \| Chalmette Refining, LLC [Member]
Statement [Line Items]
Percentage ownership interest	50.00%
Downstream [Member] \| Fujian Refining and Petrochemical Co. Ltd. [Member]
Statement [Line Items]
Percentage ownership interest	25.00%
Downstream [Member] \| Saudi Aramco Mobil Refinery Company Ltd. [Member]
Statement [Line Items]
Percentage ownership interest	50.00%
Chemical [Member] \| Al-Jubail Petrochemical Company [Member]
Statement [Line Items]
Percentage ownership interest	50.00%
Chemical [Member] \| Infineum Holdings B.V. [Member]
Statement [Line Items]
Percentage ownership interest	50.00%
Chemical [Member] \| Saudi Yanbu Petrochemical Co. [Member]
Statement [Line Items]
Percentage ownership interest	50.00%
Chemical [Member] \| Toray Tonen Specialty Separator Godo Kaisha [Member]
Statement [Line Items]
Percentage ownership interest	50.00%

Investments, Advances and Long-Term Receivables (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009
Statement [Line Items]
Reserves for long-term receivables and miscellaneous investments	$ 292	$ 368

Investments, Advances and Long-Term Receivables (Details) - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009
Investments, Advances and Long-Term Receivables
Investments (Companies carried at equity in underlying assets)	$ 17,429	$ 15,742
Advances (Companies carried at equity in underlying assets)	9,286	8,669
Total of investments and advances	26,715	24,411
Companies carried at cost or less and stock investments carried at fair value	1,557	1,577
Investments in and advance to affiliates, subsidiaries, associates, and joint ventures, total	28,272	25,988
Long-term receivables and miscellaneous investments at cost or less, net of reserves of $292 million and $368 million	7,066	5,677
Total	$ 35,338	$ 31,665

Property, Plant and Equipment and Asset Retirement Obligations (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)	Dec. 31, 2008 USD ($)
Statement [Line Items]
Accumulated depreciation and depletion	$ 174,390	$ 166,790
Interest capitalized	$ 532	$ 425	$ 510
Refinery and Lubes Basestock [Member] \| Downstream [Member]
Statement [Line Items]
Estimated useful life of equipments	25
Service Station Buildings And Fixed Improvements [Member] \| Downstream [Member]
Statement [Line Items]
Estimated useful life of equipments	20
Chemical [Member] \| Investments In Process Equipment [Member]
Statement [Line Items]
Estimated useful life of equipments	20

Property, Plant and Equipment and Asset Retirement Obligations (Property, Plant and Equipment) (Details) - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009
Statement [Line Items]
Property, plant and equipment cost	$ 373,938	$ 305,906
Property, plant and equipment, net	199,548	139,116
Upstream [Member]
Statement [Line Items]
Property, plant and equipment cost	264,136	198,036
Property, plant and equipment, net	148,152	88,319
Downstream [Member]
Statement [Line Items]
Property, plant and equipment cost	68,652	68,092
Property, plant and equipment, net	30,095	30,499
Chemical [Member]
Statement [Line Items]
Property, plant and equipment cost	29,524	28,464
Property, plant and equipment, net	14,255	13,511
Other [Member]
Statement [Line Items]
Property, plant and equipment cost	11,626	11,314
Property, plant and equipment, net	$ 7,046	$ 6,787

Property, Plant and Equipment and Asset Retirement Obligations (Asset Retirement Obligations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009
Statement [Line Items]
Beginning balance	$ 8,473	$ 5,352
Accretion expense and other provisions	563	372
Reduction due to property sales	(183)	(18)
Payments made	(638)	(448)
Liabilities incurred	1,094	156
Foreign currency translation	(45)	535
Revisions	350	2,524
Ending balance	$ 9,614	$ 8,473

Accounting for Suspended Exploratory Well Costs (Narrative) (Details)	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Number of projects that have exploratory well costs capitalized for a period greater than twelve months as of December 31, 2010	59	57	50
Number of projects that have drilling in the preceding twelve months or exploratory activity planned in the next two years as of December 31, 2010	25
Number of projects with completed exploratory activity progressing toward development as of December 31, 2010	34

Accounting for Suspended Exploratory Well Costs (Change in Capitalized Suspended Exploratory Well Costs) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Capitalized exploratory well costs, beginning balance	$ 2,005	$ 1,585	$ 1,291
Additions pending the determination of proved reserves	1,103	624	448
Charged to expense	(104)	(51)
Reclassification to wells, facilities, and equipment based on the determination of proved reserves	(136)	(200)	(101)
Other	25	47	(53)
Capitalized exploratory well costs, ending balance	$ 2,893	2,005	1,585
Ending balance attributed to equity companies included above		$ 9	$ 10

Accounting for Suspended Exploratory Well Costs (Schedule of Period End Capitalized Suspended Exploratory Well Costs) (Details) - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008	Dec. 31, 2007
Statement [Line Items]
Capitalized for a period of one year or less	$ 1,103	$ 624	$ 448
Capitalized suspended exploratory well costs, total	2,893	2,005	1,585	$ 1,291
Capitalized for a Period of Between One and Five Years [Member]
Statement [Line Items]
Capitalized suspended exploratory well costs	1,294	924	636
Capitalized for a Period of Between Five and Ten Years [Member]
Statement [Line Items]
Capitalized suspended exploratory well costs	278	220	225
Capitalized for a Period of Greater than Ten Years [Member]
Statement [Line Items]
Capitalized suspended exploratory well costs	218	237	276
Capitalized for a Period Greater than One Year [Member]
Statement [Line Items]
Capitalized suspended exploratory well costs	$ 1,790	$ 1,381	$ 1,137

Accounting for Suspended Exploratory Well Costs (Schedule of Number of Projects with Suspended Exploratory Well Costs) (Details)	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Number of projects with first capitalized well drilled in the preceding 12 months	9	18	12
Number of projects that have exploratory well costs capitalized for a period of greater than 12 months	59	57	50
Total	68	75	62

Accounting for Suspended Exploratory Well Costs (Schedule of Additional Detail for the Projects) (Details) - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008	Dec. 31, 2007
Statement [Line Items]
Capitalized exploratory well costs	$ 2,893	$ 2,005	$ 1,585	$ 1,291
Total 34 Projects [Member]
Statement [Line Items]
Capitalized exploratory well costs	692
Angola [Member] \| Project in Angola - Perpetua-Zina- Acacia [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 15
Years wells drilled, period	2008 - 2009
Australia [Member] \| Project in Australia - East Pilchard [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 10
Years wells drilled, period	2001
Indonesia [Member] \| Project in Indonesia - Natuna [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 118
Years wells drilled, period	1981 - 1983
Kazakhstan [Member] \| Project in Kazakhstan - Kairan [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 53
Years wells drilled, period	2004 - 2007
Nigeria [Member] \| Project in Nigeria - Bolia [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 15
Years wells drilled, period	2002 - 2006
Nigeria [Member] \| Project in Nigeria - Bonga North [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 34
Years wells drilled, period	2004 - 2009
Nigeria [Member] \| Project in Nigeria - Bosi [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 79
Years wells drilled, period	2002 - 2006
Nigeria [Member] \| Other 5 Projects in Nigeria [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 16
Years wells drilled, period	2001 - 2002
Norway [Member] \| Project in Norway - Gamma [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 20
Years wells drilled, period	2008 - 2009
Norway [Member] \| Project in Norway - H-North [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 15
Years wells drilled, period	2007
Norway [Member] \| Project in Norway - Lavrans [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 23
Years wells drilled, period	1995 - 1999
Norway [Member] \| Project in Norway - Noatun [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 19
Years wells drilled, period	2008
Norway [Member] \| Project in Norway - Nyk High [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 20
Years wells drilled, period	2008
Norway [Member] \| Other 8 Projects in Norway [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 34
Years wells drilled, period	1992 - 2009
Papua New Guinea [Member] \| Project in Papua New Guinea - Juha [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 28
Years wells drilled, period	2007
United Kingdom [Member] \| Project in United Kingdom - Fram [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 55
Years wells drilled, period	2009
United Kingdom [Member] \| Other 3 Projects in United Kingdom [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 21
Years wells drilled, period	2001 - 2008
United States [Member] \| Project in United States - Julia Unit [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 78
Years wells drilled, period	2007 - 2008
United States [Member] \| Project in United States - Tip Top [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 31
Years wells drilled, period	2009
Other Countries [Member] \| Other - Various 2 Projects [Member]
Statement [Line Items]
Capitalized exploratory well costs	$ 8
Years wells drilled, period	1979 - 1995

Leased Facilities (Narrative) (Details) $ in Millions	12 Months Ended
Leased Facilities (Narrative) (Details) $ in Millions	Dec. 31, 2010 USD ($)
Statement [Line Items]
Minimum undiscounted lease commitments	$ 7,776
Estimated related rental income from noncancelable subleases	$ 62

Leased Facilities (Leased Facilities) (Details) $ in Millions	Dec. 31, 2010 USD ($)
Statement [Line Items]
Lease payments under minimum commitments, 2011	$ 2,095
Lease payments under minimum commitments, 2012	1,570
Lease payments under minimum commitments, 2013	1,061
Lease payments under minimum commitments, 2014	731
Lease payments under minimum commitments, 2015	581
Lease payments under minimum commitments, 2016 and beyond	1,738
Lease payments under minimum commitments, total	7,776
Related sublease rental income, 2011	8
Related sublease rental income, 2012	8
Related sublease rental income, 2013	7
Related sublease rental income, 2014	6
Related sublease rental income, 2015	6
Related sublease rental income, 2016 and beyond	27
Related sublease rental income, total	$ 62

Leased Facilities (Net Rental Cost) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Rental cost	$ 3,762	$ 4,426	$ 4,115
Less sublease rental income	90	98	123
Net rental cost	$ 3,672	$ 4,328	$ 3,992

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Net income attributable to ExxonMobil	$ 30,460	$ 19,280	$ 45,220
Earnings per common share (dollars)	$ 6.24	$ 3.99	$ 8.7
Earnings per common share - assuming dilution (dollars)	6.22	3.98	8.66
Dividends paid per common share (dollars)	$ 1.74	$ 1.66	$ 1.55
Earnings Per Common Share [Member]
Statement [Line Items]
Net income attributable to ExxonMobil	$ 30,460	$ 19,280	$ 45,220
Weighted average number of common shares outstanding	4,885	4,832	5,194
Earnings per common share (dollars)	$ 6.24	$ 3.99	$ 8.70
Earnings Per Common Share - Assuming Dilution [Member]
Statement [Line Items]
Net income attributable to ExxonMobil	$ 30,460	$ 19,280	$ 45,220
Weighted average number of common shares outstanding	4,885	4,832	5,194
Effect of employee stock-based awards	12	16	27
Weighted average number of common shares outstanding - assuming dilution	4,897	4,848	5,221
Earnings per common share - assuming dilution (dollars)	$ 6.22	$ 3.98	$ 8.66

Financial Instruments and Derivatives (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2010 USD ($) $ / shares cubicFeet	Dec. 31, 2009 USD ($)	Dec. 31, 2008 USD ($)
Statement [Line Items]
Estimated fair value of total long-term debt including capitalized lease obligations	$ 12,800	$ 7,700
Recorded book values of total long-term debt including capitalized lease obligations	12,227	7,129
Derivative assets at fair value, net	172
Derivative liabilities at fair value, net		5
Derivative instruments net asset balance acquired as a result of XTO merger	219
Gain (loss) before-tax earnings impact of derivatives	$ 221	$ (73)	$ 154
Volume (millions of cubic feet daily) \| cubicFeet	250
Weighted average NYMEX price (per thousand cubic feet) \| $ / shares	7.02
Cash Flow Hedge [Member]
Statement [Line Items]
Gain (loss) before-tax earnings impact of derivatives	$ 218

Long-Term Debt (Narrative) (Details)
$ in Millions

12 Months Ended

Dec. 31, 2010

USD ($)

Dec. 31, 2009

USD ($)

Long-term debt due in U.S. dollars

$ 11,610

U.S. dollar equivalent at year-end exchange rates of amounts payable in foreign currencies

617

Portion of long-term debt included in current liability

345

$ 348

Long-term debt maturing, together with sinking fund payments required - 2012

3,222

Long-term debt maturing, together with sinking fund payments required - 2013

1,019

Long-term debt maturing, together with sinking fund payments required - 2014

622

Long-term debt maturing, together with sinking fund payments required - 2015

$ 601

SeaRiver Maritime Financial Holdings, Inc. [Member]

Equity method investments, ownership percentage

100

Guaranteed Deferred Interest Debentures Due 2012 [Member] | SeaRiver Maritime Financial Holdings, Inc. [Member]

Guaranteed Debt Securities Due 2011 [Member] | SeaRiver Maritime Financial Holdings, Inc. [Member]

^[1]

$ 2,389

$ 2,144

$ 13

[1]	Additional information is provided for this subsidiary on the following pages.

Long-Term Debt (Schedule of Summarized Long-Term Debt) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2010

Dec. 31, 2009

SeaRiver Maritime Financial Holdings, Inc. [Member]

$ 12,227

$ 7,129

Esso Thailand Public Company Ltd [Member]

$ 2,389

$ 2,157

Debt Instrument, maturity date range, start

Dec. 31, 2012

Debt Instrument, maturity date range, end

Dec. 31, 2017

Guaranteed Debt Securities Due 2011 [Member] | SeaRiver Maritime Financial Holdings, Inc. [Member]

$ 13

^[1]

Oct. 01, 2011

1.60%

Guaranteed Deferred Interest Debentures Due 2012 [Member] | SeaRiver Maritime Financial Holdings, Inc. [Member]

^[2],[3]

$ 13

^[2]

$ 2,389

$ 2,144

7.500% Senior Note Due 2012 [Member] | XTO Energy Inc. [Member]

^[1]

Sep. 01, 2012

$ 199

$ 15

7.50%

5.900% Senior Note Due 2012 [Member] | XTO Energy Inc. [Member]

Apr. 15, 2012

$ 233

$ 16

5.90%

6.250% Senior Note Due 2013 [Member] | XTO Energy Inc. [Member]

Aug. 01, 2012

$ 193

$ 18

6.25%

4.625% Senior Note Due 2013 [Member] | XTO Energy Inc. [Member]

Apr. 15, 2013

$ 149

$ 9

4.625%

5.750% Senior Note Due 2013 [Member] | XTO Energy Inc. [Member]

Jun. 15, 2013

$ 359

$ 37

5.75%

4.900% Senior Note Due 2014 [Member] | XTO Energy Inc. [Member]

Dec. 15, 2013

$ 267

$ 19

4.90%

5.000% Senior Note Due 2015 [Member] | XTO Energy Inc. [Member]

Feb. 01, 2014

$ 142

$ 13

5.00%

5.300% Senior Note Due 2015 [Member] | XTO Energy Inc. [Member]

Jan. 31, 2015

$ 262

$ 28

5.30%

5.650% Senior Note Due 2016 [Member] | XTO Energy Inc. [Member]

Jun. 30, 2015

$ 227

$ 27

5.65%

6.250% Senior Note Due 2017 [Member] | XTO Energy Inc. [Member]

Apr. 01, 2016

$ 534

$ 80

6.25%

5.500% Senior Note Due 2018 [Member] | XTO Energy Inc. [Member]

Aug. 01, 2017

$ 420

$ 49

5.50%

6.500% Senior Note Due 2018 [Member] | XTO Energy Inc. [Member]

Jun. 15, 2018

$ 524

$ 86

6.50%

6.100% Senior Note Due 2036 [Member] | XTO Energy Inc. [Member]

Dec. 15, 2018

$ 204

$ 29

6.10%

6.750% Senior Note Due 2037 [Member] | XTO Energy Inc. [Member]

Apr. 01, 2036

$ 329

$ 69

6.75%

6.375% Senior Note Due 2038 [Member] | XTO Energy Inc. [Member]

Aug. 01, 2037

$ 258

$ 46

6.375%

Variable Note Due 2035 [Member] | Mobil Services (Bahamas) Ltd. [Member]

Jun. 15, 2038

^[4]

$ 972

May 18, 2035

Variable Note Due 2034 [Member] | Mobil Services (Bahamas) Ltd. [Member]

0.30%

^[5]

$ 311

Sep. 15, 2034

Variable Notes Due 2012-2017 [Member] | Mobil Producing Nigeria Unlimited [Member]

0.40%

0.90%

Debt Instrument, maturity date range, start

^[6]

$ 415

$ 621

Dec. 31, 2012

Debt Instrument, maturity date range, end

Dec. 31, 2017

Variable Notes Due 2012-2017 [Member] | Esso Thailand Public Company Ltd [Member]

4.60%

5.40%

^[7]

$ 522

$ 165

Debentures Due 2021 [Member] | Mobil Corporation [Member]

1.70%

2.20%

Other long-term debt

$ 248

8.625%

Industrial revenue bonds due 2012-2040 [Member] | Combined Exxon Mobil And Affiliates [Member]

Aug. 15, 2021

Debt Instrument, maturity date range, start

Other long-term debt

^[8]

$ 2,247

$ 1,685

Dec. 31, 2012

Debt Instrument, maturity date range, end

Dec. 31, 2040

Other U.S. Dollar Obligations [Member] | Combined Exxon Mobil And Affiliates [Member]

0.20%

Other U.S. dollar obligations

^[9]

$ 454

$ 536

Other Foreign Currency Obligations [Member] | Combined Exxon Mobil And Affiliates [Member]

4.70%

5.00%

Other foreign currency obligations

$ 65

$ 66

Capitalized Lease Obligations [Member] | Combined Exxon Mobil And Affiliates [Member]

8.10%

8.80%

^[10]

$ 304

$ 368

[1]	Additional information is provided for this subsidiary on the following pages.
[2]	Additional information is provided for this subsidiary on the following pages.
[3]	Average effective interest rate of 1.6% in 2009.
[4]	Average effective interest rate of 0.3% in 2010 and 0.3% in 2009.
[5]	Average effective interest rate of 0.4% in 2010 and 0.9% in 2009.
[6]	Average effective interest rate of 4.6% in 2010 and 5.4% in 2009.
[7]	Average effective interest rate of 1.7% in 2010 and 2.2% in 2009.
[8]	Average effective interest rate of 0.2% in 2010 and 0.2% in 2009.
[9]	Average effective interest rate of 4.7% in 2010 and 5.0% in 2009.
[10]	Average imputed interest rate of 8.1% in 2010 and 8.8% in 2009.

Long-Term Debt (Statement of Income) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2010

Dec. 31, 2009

Dec. 31, 2008

Sales and other operating revenue, including sales-based taxes

^[1]

$ 370,125

$ 301,500

$ 459,579

10,677

7,143

11,081

^[2]

2,419

1,943

6,699

383,221

310,586

477,359

197,959

152,806

249,454

35,792

33,027

37,905

14,683

14,735

15,873

14,760

11,917

12,379

2,144

2,021

1,451

259

548

673

^[1]

28,547

25,936

34,508

36,118

34,819

41,719

330,262

275,809

393,962

52,959

34,777

83,397

21,561

15,119

36,530

Net income attributable to noncontrolling interests

31,398

19,658

46,867

938

378

1,647

ExxonMobil Corporation Parent Guarantor [Member]

30,460

19,280

45,220

Sales and other operating revenue, including sales-based taxes

15,382

11,352

17,481

28,401

19,852

45,664

790

813

302

39,433

30,889

48,414

84,006

62,906

111,861

40,788

31,419

48,346

7,627

7,811

8,327

2,871

2,574

3,349

1,761

1,571

1,552

251

230

192

217

1,200

3,859

(29)

53,544

44,776

65,692

30,462

18,130

46,169

(1,150)

949

Net income attributable to noncontrolling interests

30,460

19,280

45,220

SeaRiver Maritime Financial Holdings, Inc. [Member]

30,460

19,280

45,220

Sales and other operating revenue, including sales-based taxes

(2)

246

222

207

246

222

207

(244)

(211)

(153)

(90)

(81)

(56)

Net income attributable to noncontrolling interests

(154)

(130)

(97)

All Other Subsidiaries [Member]

(154)

(130)

(97)

Sales and other operating revenue, including sales-based taxes

354,743

290,148

442,098

10,589

7,060

11,055

1,629

1,130

6,397

332,483

271,663

442,305

699,444

570,001

901,855

518,961

411,689

669,107

33,400

30,805

35,298

12,482

12,852

13,364

12,999

10,346

10,827

1,893

1,791

1,259

4,035

5,126

13,143

28,547

25,936

34,508

36,089

34,848

41,652

648,406

533,393

819,158

51,038

36,608

82,697

21,649

16,350

35,637

Net income attributable to noncontrolling interests

29,389

20,258

47,060

938

378

1,647

Consolidating and Eliminating Adjustments [Member]

28,451

19,880

45,413

Sales and other operating revenue, including sales-based taxes

(28,311)

(19,776)

(45,647)

(371,920)

(302,556)

(490,764)

(400,231)

(322,332)

(536,411)

(361,790)

(290,302)

(467,999)

(5,235)

(5,589)

(5,720)

(670)

(691)

(840)

(4,239)

(6,000)

(16,536)

(371,934)

(302,582)

(491,095)

(28,297)

(19,750)

(45,316)

Net income attributable to noncontrolling interests

(28,297)

(19,750)

(45,316)

(28,297)

(19,750)

(45,316)

Consolidated [Member]

Sales and other operating revenue, including sales-based taxes

370,125

301,500

459,579

10,677

7,143

11,081

2,419

1,943

6,699

383,221

310,586

477,359

197,959

152,806

249,454

35,792

33,027

37,905

14,683

14,735

15,873

14,760

11,917

12,379

2,144

2,021

1,451

259

548

673

28,547

25,936

34,508

36,118

34,819

41,719

330,262

275,809

393,962

52,959

34,777

83,397

21,561

15,119

36,530

Net income attributable to noncontrolling interests

31,398

19,658

46,867

938

378

1,647

$ 30,460

$ 19,280

$ 45,220

[1]	Sales and other operating revenue includes sales-based taxes of $28,547 million for 2010, $25,936 million for 2009 and $34,508 million for 2008.
[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.

Long-Term Debt (Balance Sheet) (Details) - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008	Dec. 31, 2007
Statement [Line Items]
Cash and cash equivalents	$ 7,825	$ 10,693	$ 31,437	$ 33,981
Cash and cash equivalents - restricted	628
Marketable securities	2	169
Notes and accounts receivable - net	32,284	27,645
Other current assets	5,269	5,175
Total current assets	58,984	55,235
Investments, advances and long-term receivables	35,338	31,665
Property, plant and equipment - net	199,548	139,116
Other long-term assets	8,640	7,307
Total assets	302,510	233,323
Notes and loans payable	2,787	2,476
Accounts payable and accrued liabilities	50,034	41,275
Income taxes payable	9,812	8,310
Total current liabilities	62,633	52,061
Long-term debt	12,227	7,129
Postretirement benefits reserves	19,367	17,942
Deferred income tax liabilities	35,150	23,148
Other long-term liabilities	20,454	17,651
Total liabilities	149,831	117,931
Earnings reinvested	298,899	276,937
ExxonMobil share of equity	146,839	110,569
Noncontrolling interests	5,840	4,823
Total equity	152,679	115,392	$ 117,523	$ 126,044
Total liabilities and equity	302,510	233,323
ExxonMobil Corporation Parent Guarantor [Member]
Statement [Line Items]
Cash and cash equivalents	309	449
Cash and cash equivalents - restricted	371
Marketable securities
Notes and accounts receivable - net	2,104	2,050
Inventories	1,457	1,202
Other current assets	239	313
Total current assets	4,480	4,014
Investments, advances and long-term receivables	254,781	199,110
Property, plant and equipment - net	18,830	18,015
Other long-term assets	224	207
Intercompany receivables	18,186	19,637
Total assets	296,501	240,983
Notes and loans payable	1,042	43
Accounts payable and accrued liabilities	2,987	2,779
Income taxes payable
Total current liabilities	4,029	2,822
Long-term debt	295	279
Postretirement benefits reserves	9,660	8,673
Deferred income tax liabilities	642	818
Other long-term liabilities	5,632	5,286
Intercompany payables	129,404	112,536
Total liabilities	149,662	130,414
Earnings reinvested	298,899	276,937
Other equity	(152,060)	(166,368)
ExxonMobil share of equity	146,839	110,569
Noncontrolling interests
Total equity	146,839	110,569
Total liabilities and equity	296,501	240,983
SeaRiver Maritime Financial Holdings, Inc. [Member]
Statement [Line Items]
Cash and cash equivalents
Cash and cash equivalents - restricted
Marketable securities
Notes and accounts receivable - net
Inventories
Other current assets
Total current assets
Investments, advances and long-term receivables	446	449
Property, plant and equipment - net
Other long-term assets	12	24
Intercompany receivables	2,457	2,257
Total assets	2,915	2,730
Notes and loans payable	13	13
Accounts payable and accrued liabilities
Income taxes payable	3	2
Total current liabilities	16	15
Long-term debt	2,389	2,157
Postretirement benefits reserves
Deferred income tax liabilities	107	151
Other long-term liabilities
Intercompany payables	382	382
Total liabilities	2,894	2,705
Earnings reinvested	(848)	(694)
Other equity	869	719
ExxonMobil share of equity	21	25
Noncontrolling interests
Total equity	21	25
Total liabilities and equity	2,915	2,730
All Other Subsidiaries [Member]
Statement [Line Items]
Cash and cash equivalents	7,516	10,244
Cash and cash equivalents - restricted	257
Marketable securities	2	169
Notes and accounts receivable - net	30,346	25,858
Inventories	11,519	10,351
Other current assets	5,030	4,862
Total current assets	54,670	51,484
Investments, advances and long-term receivables	454,489	439,712
Property, plant and equipment - net	180,718	121,101
Other long-term assets	8,404	7,076
Intercompany receivables	528,405	442,903
Total assets	1,226,686	1,062,276
Notes and loans payable	1,732	2,420
Accounts payable and accrued liabilities	47,047	38,496
Income taxes payable	9,975	8,571
Total current liabilities	58,754	49,487
Long-term debt	9,543	4,693
Postretirement benefits reserves	9,707	9,269
Deferred income tax liabilities	34,401	22,179
Other long-term liabilities	14,822	12,365
Intercompany payables	419,262	351,879
Total liabilities	546,489	449,872
Earnings reinvested	132,357	109,603
Other equity	542,000	497,978
ExxonMobil share of equity	674,357	607,581
Noncontrolling interests	5,840	4,823
Total equity	680,197	612,404
Total liabilities and equity	1,226,686	1,062,276
Consolidating and Eliminating Adjustments [Member]
Statement [Line Items]
Cash and cash equivalents
Cash and cash equivalents - restricted
Marketable securities
Notes and accounts receivable - net	(166)	(263)
Inventories
Other current assets
Total current assets	(166)	(263)
Investments, advances and long-term receivables	(674,378)	(607,606)
Property, plant and equipment - net
Other long-term assets
Intercompany receivables	(549,048)	(464,797)
Total assets	(1,223,592)	(1,072,666)
Notes and loans payable
Accounts payable and accrued liabilities
Income taxes payable	(166)	(263)
Total current liabilities	(166)	(263)
Long-term debt
Postretirement benefits reserves
Deferred income tax liabilities
Other long-term liabilities
Intercompany payables	(549,048)	(464,797)
Total liabilities	(549,214)	(465,060)
Earnings reinvested	(131,509)	(108,909)
Other equity	(542,869)	(498,697)
ExxonMobil share of equity	(674,378)	(607,606)
Noncontrolling interests
Total equity	(674,378)	(607,606)
Total liabilities and equity	(1,223,592)	(1,072,666)
Consolidated [Member]
Statement [Line Items]
Cash and cash equivalents	7,825	10,693
Cash and cash equivalents - restricted	628
Marketable securities	2	169
Notes and accounts receivable - net	32,284	27,645
Inventories	12,976	11,553
Other current assets	5,269	5,175
Total current assets	58,984	55,235
Investments, advances and long-term receivables	35,338	31,665
Property, plant and equipment - net	199,548	139,116
Other long-term assets	8,640	7,307
Intercompany receivables
Total assets	302,510	233,323
Notes and loans payable	2,787	2,476
Accounts payable and accrued liabilities	50,034	41,275
Income taxes payable	9,812	8,310
Total current liabilities	62,633	52,061
Long-term debt	12,227	7,129
Postretirement benefits reserves	19,367	17,942
Deferred income tax liabilities	35,150	23,148
Other long-term liabilities	20,454	17,651
Intercompany payables
Total liabilities	149,831	117,931
Earnings reinvested	298,899	276,937
Other equity	(152,060)	(166,368)
ExxonMobil share of equity	146,839	110,569
Noncontrolling interests	5,840	4,823
Total equity	152,679	115,392
Total liabilities and equity	$ 302,510	$ 233,323

Long-Term Debt (Cash Flows) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Cash provided by/(used in) operating activities	$ 48,413	$ 28,438	$ 59,725
Additions to property, plant and equipment	(26,871)	(22,491)	(19,318)
Sales of long-term assets	3,261	1,545	5,985
Decrease/(increase) in restricted cash and cash equivalents	628
Net cash provided by/(used in) investing activities	(24,204)	(22,419)	(15,499)
Cash dividends to ExxonMobil shareholders	(8,948)	(8,023)	(8,058)
Net cash provided by/(used in) financing activities	(26,924)	(27,283)	(44,027)
Effects of exchange rate changes on cash	(153)	520	(2,743)
Increase/(decrease) in cash and cash equivalents	(2,868)	(20,744)	(2,544)
ExxonMobil Corporation Parent Guarantor [Member]
Statement [Line Items]
Cash provided by/(used in) operating activities	35,740	27,424	47,823
Additions to property, plant and equipment	(2,922)	(2,686)	(2,154)
Sales of long-term assets	1,484	228	162
Decrease/(increase) in restricted cash and cash equivalents	(371)
Net intercompany investing	(13,966)	(1,826)	(502)
All other investing, net	(672)
Net cash provided by/(used in) investing activities	(16,447)	(4,284)	(2,494)
Additions to short- and long-term debt
Reductions in short- and long-term debt	(3)	(3)	(4)
Additions/(reductions) in debt with three months or less maturity	997	39
Cash dividends to ExxonMobil shareholders	(8,498)	(8,023)	(8,058)
Common stock acquired	(13,093)	(19,703)	(35,734)
Net intercompany financing activity
All other financing, net	1,164	988	1,085
Net cash provided by/(used in) financing activities	(19,433)	(26,702)	(42,711)
Effects of exchange rate changes on cash
Increase/(decrease) in cash and cash equivalents	(140)	(3,562)	2,618
SeaRiver Maritime Financial Holdings, Inc. [Member]
Statement [Line Items]
Cash provided by/(used in) operating activities	63	72	68
Additions to property, plant and equipment
Sales of long-term assets
Decrease/(increase) in restricted cash and cash equivalents
Net intercompany investing	(200)	(209)	(155)
All other investing, net
Net cash provided by/(used in) investing activities	(200)	(209)	(155)
Additions to short- and long-term debt
Reductions in short- and long-term debt	(13)	(13)	(13)
Additions/(reductions) in debt with three months or less maturity
Cash dividends to ExxonMobil shareholders
Common stock acquired
Net intercompany financing activity
All other financing, net	150	150	100
Net cash provided by/(used in) financing activities	137	137	87
Effects of exchange rate changes on cash
Increase/(decrease) in cash and cash equivalents
All Other Subsidiaries [Member]
Statement [Line Items]
Cash provided by/(used in) operating activities	18,307	28,024	54,478
Additions to property, plant and equipment	(23,949)	(19,805)	(17,164)
Sales of long-term assets	1,777	1,317	5,823
Decrease/(increase) in restricted cash and cash equivalents	(257)
Net intercompany investing	13,813	1,717	476
All other investing, net	706	(1,473)	(2,166)
Net cash provided by/(used in) investing activities	(7,910)	(18,244)	(13,031)
Additions to short- and long-term debt	1,741	1,561	1,146
Reductions in short- and long-term debt	(8,644)	(1,627)	(1,799)
Additions/(reductions) in debt with three months or less maturity	(288)	(110)	143
Cash dividends to ExxonMobil shareholders	(5,697)	(27,082)	(42,644)
Net intercompany financing activity	202	168	81
All other financing, net	(286)	(392)	(793)
Net cash provided by/(used in) financing activities	(12,972)	(27,482)	(43,866)
Effects of exchange rate changes on cash	(153)	520	(2,743)
Increase/(decrease) in cash and cash equivalents	(2,728)	(17,182)	(5,162)
Consolidating and Eliminating Adjustments [Member]
Statement [Line Items]
Cash provided by/(used in) operating activities	(5,697)	(27,082)	(42,644)
Additions to property, plant and equipment
Sales of long-term assets
Decrease/(increase) in restricted cash and cash equivalents
Net intercompany investing	353	318	181
All other investing, net
Net cash provided by/(used in) investing activities	353	318	181
Additions to short- and long-term debt
Reductions in short- and long-term debt
Additions/(reductions) in debt with three months or less maturity
Cash dividends to ExxonMobil shareholders	5,697	27,082	42,644
Common stock acquired
Net intercompany financing activity	(202)	(168)	(81)
All other financing, net	(151)	(150)	(100)
Net cash provided by/(used in) financing activities	5,344	26,764	42,463
Effects of exchange rate changes on cash
Increase/(decrease) in cash and cash equivalents
Consolidated [Member]
Statement [Line Items]
Cash provided by/(used in) operating activities	48,413	28,438	59,725
Additions to property, plant and equipment	(26,871)	(22,491)	(19,318)
Sales of long-term assets	3,261	1,545	5,985
Decrease/(increase) in restricted cash and cash equivalents	(628)
All other investing, net	34	(1,473)	(2,166)
Net cash provided by/(used in) investing activities	(24,204)	(22,419)	(15,499)
Additions to short- and long-term debt	1,741	1,561	1,146
Reductions in short- and long-term debt	(8,660)	(1,643)	(1,816)
Additions/(reductions) in debt with three months or less maturity	709	(71)	143
Cash dividends to ExxonMobil shareholders	(8,498)	(8,023)	(8,058)
Common stock acquired	(13,093)	(19,703)	(35,734)
Net intercompany financing activity
All other financing, net	877	596	292
Net cash provided by/(used in) financing activities	(26,924)	(27,283)	(44,027)
Effects of exchange rate changes on cash	(153)	520	(2,743)
Increase/(decrease) in cash and cash equivalents	$ (2,868)	$ (20,744)	$ (2,544)

Incentive Program (Narrative) (Details) $ / shares in Units, shares in Thousands	12 Months Ended
	Dec. 31, 2010 USD ($) $ / shares shares	Dec. 31, 2009 USD ($) shares	Dec. 31, 2008 USD ($) shares
Statement [Line Items]
Minimum ownership of affiliates needed for awards	50.00%
Number of shares issuable under 2003 incentive program \| shares	220,000
Remaining shares available for award under 2003 incentive program \| shares	141,939
Options and stock appreciation rights grant, minimum percentage of market value, date of grant	100.00%
Award grant, maximum life or term, years	<font class="_mt">10</font>
Cash received from stock option exercises	$ 1,043,000,000	$ 752,000,000	$ 753,000,000
Cash tax benefit realized for options exercised	89,000,000	164,000,000	273,000,000
Aggregate intrinsic value of stock options exercised	539,000,000	563,000,000	894,000,000
Intrinsic value, outstanding stock options	868,000,000
Total estimated fair value calculated at acquisition for converted XTO stock-based awards	$ 352,000,000
Percent of awards having vesting periods of two or three year granted to senior executives as part of merger	50.00%
Percent of awards having vesting periods of one year granted to senior executives as part of merger	50.00%
Years until first 50 percent of awards granted to certain XTO executives vest	1
Years until second 50 percent of awards granted to certain XTO executives vest minimum	2
Years until second 50 percent of awards granted to certain XTO executives vest maximum	3
Converted XTO Performance Stock Awards [Member]
Statement [Line Items]
Converted performance stock awards \| shares	157
Fair value converted XTO performance awards	$ 5,000,000
Non-Vested XTO Stock Options [Member]
Statement [Line Items]
Compensation cost charged against income	2,000,000
Aggregate intrinsic value of stock options exercisable	$ 865,000,000
Stock Options [Member]
Statement [Line Items]
Compensation cost charged against income		$ 0	$ 0
Stock options exercisable, vesting period, years	3
Unvested converted stock options at period end \| shares	574
Options that vest ratably \| shares	130
Options that vest at stock prices \| shares	444
Options that vest at stock price, minimum \| $ / shares	$ 76.08
Options that vest at stock price, maximum \| $ / shares	$ 126.80
Restricted Stock [Member]
Statement [Line Items]
Long-term incentive awards \| shares	10,648	10,133	10,116
Award vesting period, first half of awards, years	3
Awards granted to senior executives, vesting periods, first half of awards, years	5
Awards granted to senior executives, vesting periods, remaining awards, years	<font class="_mt">10</font>
Unrecognized compensation cost	$ 2,133,000,000
Unrecognized compensation cost, weighted-average period of recognition, years	4.3
Compensation cost charged against income	$ 801,000,000	$ 723,000,000	$ 648,000,000
Income tax benefit recognized in income	81,000,000	76,000,000	75,000,000
Fair value of shares/awards vested	718,000,000	763,000,000	438,000,000
Cash payments, vested restricted stock units	$ 42,000,000	$ 41,000,000	$ 25,000,000
Award vesting period, maximum	7
Percent of the shares in each award vesting after three years	50.00%
Percent of the shares in each award vesting after seven years	50.00%
Awards having vesting periods of one year granted to senior executives as part of merger	50.00%
Percent of awards having vesting periods of two or three year granted to senior executives as part of merger	50.00%
Years until first 50 percent of awards granted to certain XTO executives vest	5
Vested, shares \| shares	(10,377)
Performance Stock [Member]
Statement [Line Items]
Unrecognized compensation cost	$ 1,000,000
Compensation cost charged against income	$ 3,000,000
Vested, shares \| shares	80
1998 Plan [Member]
Statement [Line Items]
Maximum term in years	10
2004 Plan [Member]
Statement [Line Items]
Maximum term in years	7
Stock Option [Member] \| Stock Options [Member] \| Non-Vested XTO Stock Options [Member]
Statement [Line Items]
Unrecognized compensation cost	$ 1,000,000
Acquisition of XTO Energy Inc [Member]
Statement [Line Items]
Long-term incentive awards \| shares	4,206
Fair value of shares/awards vested	$ 182,000,000
Converted stock options granted \| shares	12,393
Unvested converted stock options at grant date \| shares	893
Period the majority of converted XTO awards vest over in annual installments minimum	3
Period the majority of converted XTO awards vest over in annual installments maximum	3.5
Period over which stock options granted by XTO to certain senior XTO employees vest and become exercisable	1
Acquisition of XTO Energy Inc [Member] \| Granted And Converted Restricted Stock [Member]
Statement [Line Items]
Converted restricted stock awards \| shares	2,783
Granted restricted stock awards \| shares	1,423

Incentive Program (Summary of Restricted Stock and Units Outstanding) (Details) - Restricted Stock [Member] - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Issued and outstanding restricted stock, shares	43,503
2009 award issued in 2010, shares	10,132
Vested, shares	(10,377)
Forfeited, shares	(158)
Issued and outstanding restricted stock, shares	47,306	43,503
Issued and outstanding at January 1, weighted-average grant-date fair value per share	$ 67.52
Awards granted in calendar year, issued in following year, weighted-average grant-date fair value per share	66.07	$ 75.40	$ 78.24
Vested, weighted-average grant-date fair value per share	61.72
Forfeited, weighted-average grant-date fair value per share	67.91
Issued and outstanding at December 31, weighted-average grant-date fair value per share	$ 69.74	$ 67.52
Acquisition of XTO Energy Inc [Member]
Statement [Line Items]
Merger-related granted and converted XTO awards, shares	4,206
Merger-related granted and converted XTO awards, weighted-average grant date fair value per share	59.31

Incentive Program (Summary of Grant Value of Restricted Stock and Units) (Details) - Restricted Stock [Member] - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Grant price	$ 66.07	$ 75.40	$ 78.24
Restricted stock and units settled in stock	$ 672	$ 711	$ 735
Units settled in cash	60	53	56
Total value	982	764	791
Acquisition of XTO Energy Inc [Member]
Statement [Line Items]
Merger-related granted and converted XTO awards	$ 250

Incentive Program (Converted Performance Stock Awards) (Details) shares in Thousands	12 Months Ended
	Dec. 31, 2010 $ / shares shares
Vesting of Converted Performance Stock 2 [Member]
Statement [Line Items]
Converted performance stock awards, vesting price \| $ / shares	$ 108.49
Converted performance stock awards, shares \| shares	38
Vesting of Converted Performance Stock 3 [Member]
Statement [Line Items]
Converted performance stock awards, vesting price \| $ / shares	$ 119.76
Converted performance stock awards, shares \| shares	38

Incentive Program (Changes that Occurred in Stock Options) (Details) shares in Thousands	12 Months Ended
	Dec. 31, 2010 $ / shares shares
Statement [Line Items]
Outstanding at December 31, weighted average remaining contractual term, in years	2.0
Exercisable at December 31, weighted average remaining contractual term	1.9
Stock Option [Member]
Statement [Line Items]
Outstanding at January 1, shares \| shares	41,473
ShareBasedCompensationSharesAuthorizedUnderStockOptionPlansExercisePriceRangeOutstandingOptionsWeightedAverageExercisePriceBeginningBalance \| $ / shares	$ 40.92
Exercised, shares \| shares	(24,305)
Exercised, avg. exercise price \| $ / shares	$ 43.62
Forfeited, shares \| shares	(52)
Forfeited, avg. exercise price \| $ / shares	$ 45.91
Outstanding at December 31, shares \| shares	29,509
Outstanding at December 31, avg. exercise price \| $ / shares	$ 44.65
Exercisable at December 31, shares \| shares	28,935
Exercisable at December 31, avg. exercise price \| $ / shares	$ 43.94
Acquisition of XTO Energy Inc [Member]
Statement [Line Items]
Merger-related converted XTO awards, number of shares \| shares	12,393
Merger-related converted XTO awards, avg. exercise price \| $ / shares	$ 55.15

Incentive Program (XTO Merger-Related Fair Value Determination) (Details)	12 Months Ended
	Dec. 31, 2010
Statement [Line Items]
Weighted average expected term, years	2.5
Range of risk-free interest rates minimum	0.10%
Range of risk-free interest rates maximum	2.60%
Weighted average risk-free interest rates	0.90%
Dividend yield	3.00%
Weighted average volatility	28.50%
Range of volatility minimum	22.50%
Range of volatility maximum	33.60%

Litigation and Other Contingencies (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2010	Jun. 27, 2007	May 01, 2007
Statement [Line Items]
Total guarantees	$ 8,771
Percentage ownership interest in Cerro Negro Project			41.67%
Net book investment in Cerro Negro Project	750
Equity Company Obligations [Member]
Statement [Line Items]
Total guarantees	5,290
Guarantees, Notes, Loans And Performance [Member]
Statement [Line Items]
Total guarantees	$ 8,771
Expropriation of Assets [Member]
Statement [Line Items]
Percentage ownership interest in Cerro Negro Project		41.67%

Litigation and Other Contingencies (Schedule of Guarantees) (Details) $ in Millions	Dec. 31, 2010 USD ($)
Statement [Line Items]
Total guarantees	$ 8,771
Equity Company Obligations [Member]
Statement [Line Items]
Total guarantees	5,290
Other Third Party Obligations [Member]
Statement [Line Items]
Total guarantees	$ 3,481

Litigation and Other Contingencies (Schedule of Unconditional Purchase Obligations) (Details)
$ in Millions

Dec. 31, 2010

USD ($)

2011

$ 287

^[1]

2012-2015

748

^[1]

2016 and beyond

487

^[1]

Unconditional purchase obligation

1,522

^[1]

1,522

^[1]

Imputed interest

273

Equity Company Obligations [Member]

Unconditional purchase obligation

996

996

Total Obligations [Member]

Present value of these commitments

$ 1,249

[1]	Undiscounted obligations of $1,522 million mainly pertain to pipeline throughput agreements and include $996 million of obligations to equity companies. The present value of these commitments, which excludes imputed interest of $273 million, totaled $1,249 million.

Pension and Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Health care cost trend rate	6.00%
Health care cost trend rate projected in 2015	4.50%
Year that rate reaches ultimate trend rate	2015
Effect of one percentage point increase on service and interest costs	$ 57
Effect of one percentage point increase on postretirement benefit obligation	599
Effect of one percentage point decrease on service and interest costs	45
Effect of one percentage point decrease on postretirement benefit obligation	494
Costs for defined contribution plans	$ 347	$ 339	$ 309
Pension Benefits - U.S. [Member]
Statement [Line Items]
Target asset allocation, equity securities	60.00%
Target asset allocation, debt securities	40.00%
Target asset allocation, venture capital	5.00%
Pension Benefits - Non-U.S. [Member]
Statement [Line Items]
Target asset allocation, equity securities	56.00%
Target asset allocation, debt securities	41.00%
Target asset allocation, real estate funds	3.00%
Target asset allocation, venture capital	3.00%

Pension and Other Postretirement Benefits (Benefit Obligations and Plan Assets Associated with Principal Benefit Plans) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2010

Dec. 31, 2009

Dec. 31, 2008

Medicare subsidy receipts

$ 15

$ 28

Long-term rate of compensation increase

Discount rate

5.50%

6.00%

5.00%

Benefit obligation at January 1

$ 13,981

$ 13,272

Service cost

468

438

$ 378

Interest cost

798

809

729

Actuarial loss/(gain)

553

1,126

Plan amendments, other

Benefit obligation at December 31

15,007

13,981

13,272

Accumulated benefit obligation at December 31

$ 12,764

$ 11,615

Long-term rate of compensation increase

Discount rate

4.80%

5.20%

5.20%

5.00%

Benefit obligation at January 1

$ 23,344

$ 19,990

Service cost

480

421

434

Interest cost

1,175

1,121

1,152

Actuarial loss/(gain)

1,672

1,280

Benefit obligation at December 31

169

1,676

Plan amendments, other

163

25,722

23,344

19,990

Accumulated benefit obligation at December 31

$ 22,958

$ 20,909

Long-term rate of compensation increase

Discount rate

5.50%

6.00%

5.00%

Benefit obligation at January 1

$ 6,748

$ 6,633

Service cost

101

100

Interest cost

395

408

414

Actuarial loss/(gain)

277

(49)

Benefit obligation at December 31

Plan amendments, other

178

7,331

6,748

$ 6,633

Benefit Payments for Funded and Unfunded Plans [Member] | Pension Benefits - U.S. [Member]

Benefit Payments for Funded and Unfunded Plans [Member] | Pension Benefits - Non-U.S. [Member]

Benefits paid

^[1],[2]

(873)

(1,665)

Benefit Payments for Funded and Unfunded Plans [Member] | Other Postretirement Benefits [Member]

Benefits paid

^[1],[2]

(1,281)

(1,174)

Benefits paid

^[1],[2]

$ (394)

$ (480)

[1]	Benefit payments for funded plans.
[2]	For 2010 and 2009, other postretirement benefits paid are net of $15 million and $28 million of Medicare subsidy receipts, respectively.

Pension and Other Postretirement Benefits (Change in Plan Assets of Pension and Other Postretirement Benefits) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2010

Dec. 31, 2009

Actual return on plan assets

Fair value at January 1

$ 10,277

$ 6,634

1,235

2,013

Fair value at December 31

Company contribution

3,070

Other

10,835

10,277

Actual return on plan assets

Fair value at January 1

15,401

11,260

1,482

2,201

Fair value at December 31

1,300

Company contribution

1,184

1,456

Other

(528)

(21)

16,765

15,401

Actual return on plan assets

Fair value at January 1

514

443

Fair value at December 31

Company contribution

Other

(1)

558

514

Benefit Payments for Funded Plans [Member] | Pension Benefits - U.S. [Member]

Defined Benefit Plan, Benefits Paid

^[1]

(677)

(1,440)

Benefit Payments for Funded Plans [Member] | Pension Benefits - Non-U.S. [Member]

Defined Benefit Plan, Benefits Paid

^[1]

(873)

(795)

Benefit Payments for Funded Plans [Member] | Other Postretirement Benefits [Member]

Defined Benefit Plan, Benefits Paid

^[1]

$ (59)

$ (57)

[1]	Benefit payments for funded plans.

Pension and Other Postretirement Benefits (Summary of Assets in Excess of/(Less Than) Benefit Obligation) (Details) - USD ($)
$ in Millions

Dec. 31, 2010

Dec. 31, 2009

^[1]

$ (4,172)

$ (3,704)

Pension Benefits - U.S. [Member] | Funded Plans [Member]

(4,172)

(3,704)

Pension Benefits - U.S. [Member] | Unfunded Plans [Member]

(2,349)

(1,940)

Unfunded plans

(1,823)

(1,764)

^[1]

(8,957)

(7,943)

Pension Benefits - Non-U.S. [Member] | Funded Plans [Member]

(8,957)

(7,943)

Pension Benefits - Non-U.S. [Member] | Unfunded Plans [Member]

(2,769)

(2,085)

Unfunded plans

$ (6,188)

$ (5,858)

[1]	Fair value of assets less benefit obligation shown on the preceding page.

Pension and Other Postretirement Benefits (Assets Recorded in Balance Sheet and Other Comprehensive Income) (Details) - USD ($)
$ in Millions

Dec. 31, 2010

Dec. 31, 2009

$ (19,367)

$ (17,942)

Balance at December 31

^[1]

(4,172)

(3,704)

Other assets

Current liabilities

(257)

(235)

(3,916)

(3,470)

Total recorded

(4,172)

(3,704)

Prior service cost/(credit)

5,028

5,830

Total recorded in accumulated other comprehensive income

5,111

5,835

Balance at December 31

^[1]

(8,957)

(7,943)

Other assets

400

961

Current liabilities

(336)

(348)

(9,021)

(8,556)

Total recorded

(8,957)

(7,943)

Prior service cost/(credit)

7,795

7,036

674

622

Total recorded in accumulated other comprehensive income

8,469

7,658

Balance at December 31

^[1]

(6,773)

(6,234)

Current liabilities

(343)

(318)

(6,430)

(5,916)

Total recorded

(6,773)

(6,234)

Prior service cost/(credit)

1,985

1,878

154

181

Total recorded in accumulated other comprehensive income

$ 2,139

$ 2,059

[1]	Fair value of assets less benefit obligation shown on the preceding page.

Pension and Other Postretirement Benefits (Long-Term Rates of Pension and Other Postretirement Benefits) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Pension Benefits - U.S. [Member]
Statement [Line Items]
Discount rate	6.00%	6.25%	6.25%
Long-term rate of return on funded assets	7.50%	8.00%	9.00%
Long-term rate of compensation increase	5.00%	5.00%	5.00%
Service cost	$ 468	$ 438	$ 378
Interest cost	798	809	729
Expected return on plan assets	(726)	(656)	(915)
Amortization of actuarial loss/(gain)	525	694	239
Amortization of prior service cost	2		(2)
Net pension enhancement and curtailment/settlement expense	321	485	174
Net periodic benefit cost	1,388	1,770	603
Net actuarial loss/(gain)	44	(231)	5,275
Amortization of actuarial (loss)/gain	(846)	(1,179)	(413)
Prior service cost/(credit)	80
Amortization of prior service (cost)	(2)		2
Total recorded in other comprehensive income	(724)	(1,410)	4,864
Total recorded in net periodic benefit cost and other comprehensive income, before tax	$ 664	$ 360	$ 5,467
Pension Benefits - Non-U.S. [Member]
Statement [Line Items]
Discount rate	5.20%	5.50%	5.40%
Long-term rate of return on funded assets	6.70%	7.30%	7.50%
Long-term rate of compensation increase	5.00%	4.70%	4.50%
Service cost	$ 480	$ 421	$ 434
Interest cost	1,175	1,121	1,152
Expected return on plan assets	(1,010)	(886)	(1,200)
Amortization of actuarial loss/(gain)	554	648	318
Amortization of prior service cost	84	79	93
Net pension enhancement and curtailment/settlement expense	9	2	32
Net periodic benefit cost	1,292	1,385	829
Net actuarial loss/(gain)	1,202	(33)	4,837
Amortization of actuarial (loss)/gain	(563)	(650)	(350)
Prior service cost/(credit)	160	69	16
Amortization of prior service (cost)	(84)	(79)	(93)
Foreign exchange rate changes	96	608	(997)
Total recorded in other comprehensive income	811	(85)	3,413
Total recorded in net periodic benefit cost and other comprehensive income, before tax	$ 2,103	$ 1,300	$ 4,242
Other Postretirement Benefits [Member]
Statement [Line Items]
Discount rate	6.00%	6.25%	6.25%
Long-term rate of return on funded assets	7.50%	8.00%	9.00%
Long-term rate of compensation increase	5.00%	5.00%	5.00%
Service cost	$ 101	$ 94	$ 100
Interest cost	395	408	414
Expected return on plan assets	(37)	(35)	(59)
Amortization of actuarial loss/(gain)	147	176	197
Amortization of prior service cost	52	69	76
Net periodic benefit cost	658	712	728
Net actuarial loss/(gain)	251	(107)	13
Amortization of actuarial (loss)/gain	(147)	(176)	(197)
Prior service cost/(credit)	26
Amortization of prior service (cost)	(52)	(69)	(76)
Foreign exchange rate changes	2	2	(3)
Total recorded in other comprehensive income	80	(350)	(263)
Total recorded in net periodic benefit cost and other comprehensive income, before tax	$ 738	$ 362	$ 465

Pension and Other Postretirement Benefits (Summary of the Change in Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Total (charge)/credit to other comprehensive income, before tax	$ (167)	$ 1,845	$ (8,014)
(Charge)/credit to income tax	35	(591)	2,723
(Charge)/credit to investment in equity companies	11	(133)	(27)
(Charge)/credit to other comprehensive income including noncontrolling interests, after tax	(121)	1,121	(5,318)
Charge/(credit) to equity of noncontrolling interests	95	93	224
(Charge)/credit to other comprehensive income attributable to ExxonMobil	(26)	1,214	(5,094)
Pension Benefits - U.S. [Member]
Statement [Line Items]
Total (charge)/credit to other comprehensive income, before tax	724	1,410	(4,864)
Pension Benefits - Non-U.S. [Member]
Statement [Line Items]
Total (charge)/credit to other comprehensive income, before tax	(811)	85	(3,413)
Other Postretirement Benefits [Member]
Statement [Line Items]
Total (charge)/credit to other comprehensive income, before tax	$ (80)	$ 350	$ 263

Pension and Other Postretirement Benefits (Fair Value of Benefit Plan Assets- Other Postretirement) (Details) - Other Postretirement Benefits [Member] - USD ($)
$ in Millions

Dec. 31, 2010

Dec. 31, 2009

Dec. 31, 2008

U.S. Equity Securities [Member]

$ 558

$ 514

$ 443

Non-U.S. Equity Securities [Member]

180

166

191

181

Private Equity [Member]

Corporate Debt Securities [Member]

Government Debt Securities [Member]

Asset-backed Debt Securities [Member]

117

Private Mortgage Debt Securities [Member]

Cash [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member] | Cash [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member] | U.S. Equity Securities [Member]

550

504

Significant Other Observable Inputs (Level 2) [Member] | Non-U.S. Equity Securities [Member]

^[1]

180

166

Significant Other Observable Inputs (Level 2) [Member] | Corporate Debt Securities [Member]

^[1]

191

181

Significant Other Observable Inputs (Level 2) [Member] | Government Debt Securities [Member]

^[2]

Significant Other Observable Inputs (Level 2) [Member] | Asset-backed Debt Securities [Member]

^[2]

117

Significant Unobservable Inputs (Level 3) [Member]

^[2]

Significant Unobservable Inputs (Level 3) [Member] | Private Equity [Member]

Significant Unobservable Inputs (Level 3) [Member] | Private Mortgage Debt Securities [Member]

^[3]

^[4]

$ 2

$ 3

[1]	For U.S. and non-U.S. equity securities held in the form of fund units that are redeemable at the measurement date, the unit value is treated as a Level 2 input. The fair value of the securities owned by the funds is based on observable quoted prices on active exchanges, which are Level 1 inputs.
[2]	For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions.
[3]	For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings.
[4]	For private mortgages, fair value is based on proprietary credit spread matrices developed using market data and monthly surveys of active mortgage bankers.

Pension and Other Postretirement Benefits (Change in the Fair Value of Level 3 Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009
Pension Benefits - U.S. [Member] \| Private Equity [Member]
Statement [Line Items]
Fair value at January 1	$ 349	$ 346
Net realized gains/(losses)		4
Net unrealized gains/(losses)	47	(35)
Net purchases/(sales)	12	34
Fair value at December 31	408	349
Pension Benefits - U.S. [Member] \| Private Mortgages [Member]
Statement [Line Items]
Fair value at January 1	280	476
Net realized gains/(losses)	36	11
Net unrealized gains/(losses)	(3)	7
Net purchases/(sales)	(185)	(214)
Fair value at December 31	128	280
Pension Benefits - Non-U.S. [Member] \| Private Equity [Member]
Statement [Line Items]
Fair value at January 1	239	238
Net realized gains/(losses)	(1)	(10)
Net unrealized gains/(losses)	26	(35)
Net purchases/(sales)	51	46
Fair value at December 31	315	239
Pension Benefits - Non-U.S. [Member] \| Private Mortgages [Member]
Statement [Line Items]
Fair value at January 1	5	5
Net realized gains/(losses)	(1)
Net unrealized gains/(losses)	1
Net purchases/(sales)	(1)
Fair value at December 31	4	5
Pension Benefits - Non-U.S. [Member] \| Real Estate Funds [Member]
Statement [Line Items]
Fair value at January 1	413	409
Net realized gains/(losses)		(7)
Net unrealized gains/(losses)	(4)	(11)
Net purchases/(sales)	8	22
Fair value at December 31	417	413
Other Postretirement Benefits [Member] \| Private Equity [Member]
Statement [Line Items]
Fair value at January 1	4	4
Net unrealized gains/(losses)	1
Fair value at December 31	5	4
Other Postretirement Benefits [Member] \| Private Mortgages [Member]
Statement [Line Items]
Fair value at January 1	3	6
Net realized gains/(losses)	1
Net purchases/(sales)	(2)	(3)
Fair value at December 31	$ 2	$ 3

Pension and Other Postretirement Benefits (Pension Plans with Accumulated Benefit Obligation in Excess of Plan Assets) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2010

Dec. 31, 2009

^[1]

$ 159

^[2]

^[1]

835

^[2]

^[1]

615

^[2]

^[1]

159

Funded Pension Plans [Member] | Pension Benefits - U.S. [Member]

^[2]

13,184

$ 12,217

11,383

10,312

Funded Pension Plans [Member] | Pension Benefits - Non-U.S. [Member]

10,834

10,276

9,865

13,152

9,074

12,260

Unfunded Pension Plans [Member] | Pension Benefits - U.S. [Member]

7,131

10,447

1,823

1,764

Unfunded Pension Plans [Member] | Pension Benefits - Non-U.S. [Member]

1,381

1,303

6,188

5,858

$ 5,413

$ 5,180

[1]	The Corporation amortizes the net balance of actuarial losses/(gains) as a component of net periodic benefit cost over the average remaining service period of active plan participants.
[2]	The Corporation amortizes prior service cost on a straight-line basis as permitted under authoritative guidance for defined benefit pension and other postretirement benefit plans.

Pension and Other Postretirement Benefits (Expected Contribution Pension Benefits and Other Postretirement Benefits) $ in Millions	Dec. 31, 2010 USD ($)
Pension Benefits - U.S. [Member]
Statement [Line Items]
Contributions expected in 2011	$ 270
Benefits payments expected in 2011	1,454
Benefits payments expected in 2012	1,483
Benefits payments expected in 2013	1,512
Benefits payments expected in 2014	1,451
Benefits payments expected in 2015	1,392
Benefits payments expected in 2016-2020	6,079
Pension Benefits - Non-U.S. [Member]
Statement [Line Items]
Contributions expected in 2011	1,130
Benefits payments expected in 2011	1,299
Benefits payments expected in 2012	1,281
Benefits payments expected in 2013	1,316
Benefits payments expected in 2014	1,362
Benefits payments expected in 2015	1,393
Benefits payments expected in 2016-2020	8,325
Gross Other Postretirement Benefits [Member]
Statement [Line Items]
Benefits payments expected in 2011	440
Benefits payments expected in 2012	456
Benefits payments expected in 2013	474
Benefits payments expected in 2014	489
Benefits payments expected in 2015	502
Benefits payments expected in 2016-2020	2,662
Other Postretirement Benefits Medicare Subsidy Receipts [Member]
Statement [Line Items]
Benefits payments expected in 2011	23
Benefits payments expected in 2012	25
Benefits payments expected in 2013	26
Benefits payments expected in 2014	28
Benefits payments expected in 2015	29
Benefits payments expected in 2016-2020	$ 163

Disclosures about Segments and Related Information (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Interest related to Valdez punitive damages award		$ 140
Non-debt related interest expense	$ 41	$ 500	$ 498
Upstream Non-U.S. [Member]
Statement [Line Items]
Gain on sale of natural gas transportation business in Germany			1,620
Corporate and Financing [Member]
Statement [Line Items]
Charges related to Valdez litigation			$ 460

Disclosures about Segments and Related Information (Schedule of Segments and Related Information) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2010

Dec. 31, 2009

Dec. 31, 2008

$ 28,547

$ 25,936

$ 34,508

Upstream U.S. [Member]

4,272

2,893

6,243

1,261

1,216

1,954

^[1]

8,895

3,406

6,767

8,102

6,718

9,617

3,506

1,768

1,391

2,219

1,451

3,451

52,300

2,973

2,699

2,636

2,440

2,248

Upstream Non-U.S. [Member]

76,725

24,940

23,056

19,825

14,214

29,159

8,415

5,269

7,597

^[1]

26,046

21,355

32,346

39,066

32,982

55,069

7,574

6,376

7,266

18,627

15,183

30,654

16,937

13,307

10,545

9,625

8,864

7,787

115,646

102,372

83,750

Downstream U.S. [Member]

770

(153)

1,649

(102)

(2)

^[1]

93,599

76,467

116,701

13,546

10,168

16,225

681

687

656

360

(164)

728

888

1,449

1,550

254

323

456

Downstream Non-U.S. [Member]

18,378

17,493

16,328

2,797

1,934

6,502

225

188

518

^[1]

206,042

173,404

265,359

52,697

39,190

65,723

1,565

1,665

1,672

560

(22)

1,990

1,332

1,447

1,552

1,240

1,190

1,382

47,402

45,098

42,044

Chemical U.S. [Member]

2,422

769

724

171

164

105

^[1]

13,402

9,962

14,136

9,694

7,185

9,925

421

400

410

736

281

177

247

294

413

285

259

241

Chemical Non-U.S. [Member]

7,148

7,044

6,856

2,491

1,540

2,233

1,163

906

1,411

^[1]

22,119

16,885

24,252

8,421

6,947

9,749

432

457

422

347

(182)

1,733

2,553

1,987

3,586

2,873

2,384

Corporate and Financing [Member]

19,087

17,117

13,300

(2,117)

(1,917)

(1,290)

(581)

(498)

(502)

^[1]

282

284

273

581

564

562

Interest revenue

118

179

1,400

189

450

519

(1,288)

(1,428)

(480)

719

468

572

(197)

(207)

(40)

18,124

19,259

42,718

Corporate Total [Member]

30,460

19,280

45,220

10,677

7,143

11,081

^[1]

370,125

301,500

459,579

14,760

11,917

12,379

Interest revenue

118

179

1,400

259

548

673

21,561

15,119

36,530

74,156

22,491

19,318

17,429

15,742

14,458

$ 302,510

$ 233,323

$ 228,052

[1]	Sales and other operating revenue includes sales-based taxes of $28,547 million for 2010, $25,936 million for 2009 and $34,508 million for 2008.

Disclosures about Segments and Related Information (Schedule of Geographic Sales and Other Operating Revenue) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2010

Dec. 31, 2009

Dec. 31, 2008

^[1]

$ 370,125

$ 301,500

$ 459,579

28,547

25,936

34,508

U.S. [Member]

^[1]

115,906

89,847

137,615

Non-U.S. [Member]

^[1]

254,219

211,653

321,964

Canada [Member]

^[1]

27,243

21,151

33,677

Japan [Member]

^[1]

27,143

22,054

30,126

United Kingdom [Member]

^[1]

24,637

20,293

29,764

Belgium [Member]

^[1]

21,139

16,857

25,399

Germany [Member]

^[1]

14,301

14,839

20,591

Italy [Member]

^[1]

14,132

12,997

17,953

France [Member]

^[1]

13,920

12,042

18,530

Singapore [Member]

^[1]

$ 11,088

$ 8,400

$ 11,059

[1]	Sales and other operating revenue includes sales-based taxes of $28,547 million for 2010, $25,936 million for 2009 and $34,508 million for 2008.

Disclosures about Segments and Related Information (Schedule of Long-Lived Assets by Geographic Regions) (Details) - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Long-lived assets	$ 199,548	$ 139,116	$ 121,346
U.S. [Member]
Statement [Line Items]
Long-lived assets	86,021	37,138	35,548
Non-U.S. [Member]
Statement [Line Items]
Long-lived assets	113,527	101,978	85,798
Canada [Member]
Statement [Line Items]
Long-lived assets	20,879	15,919	12,018
Nigeria [Member]
Statement [Line Items]
Long-lived assets	11,429	11,046	9,227
Singapore [Member]
Statement [Line Items]
Long-lived assets	8,610	7,238	5,113
Angola [Member]
Statement [Line Items]
Long-lived assets	8,570	7,320	6,129
Norway [Member]
Statement [Line Items]
Long-lived assets	6,988	7,251	5,856
Australia [Member]
Statement [Line Items]
Long-lived assets	6,570	4,247	2,857
United Kingdom [Member]
Statement [Line Items]
Long-lived assets	6,177	7,609	5,778
Kazakhstan [Member]
Statement [Line Items]
Long-lived assets	$ 5,938	$ 4,748	$ 3,535

Income, Sales-Based and Other Taxes (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Net credits for effect of changes in tax laws and rates	$ (175)	$ 9	$ 300
Reconciliation between income tax expense and theoretical U.S. tax rate, applied rate	35.00%	35.00%	35.00%
Indefinitely reinvested, undistributed earnings from subsidiary companies outside the U.S.	$ 35,000
Potential percentage increase in unrecognized tax benefits	20.00%
Potential percentage decrease in unrecognized tax benefits	5.00%
Credit of net interest expense on income tax reserves	$ 39
Interest expense on income tax reserves		$ 135	$ 137
Interest payable on income tax reserves	$ 636	$ 771

Income, Sales-Based and Other Taxes (Schedule of Income, Sales-Based and Other Taxes) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2010

Dec. 31, 2009

Dec. 31, 2008

U.S. tax on non-U.S. operations

Current

$ 22,317

$ 14,992

$ 34,382

Deferred - net

(1,142)

(15)

1,457

230

Total federal and non-U.S.

21,221

15,009

36,069

State

340

110

461

Total income taxes

21,561

15,119

36,530

^[1]

28,547

25,936

34,508

Other taxes and duties included in production and manufacturing expenses

36,118

34,819

41,719

2,238

2,017

2,635

Other taxes and duties included in SG&A expenses

771

735

869

Total other taxes and duties

39,127

37,571

45,223

89,235

78,626

116,261

U.S. [Member]

U.S. tax on non-U.S. operations

Current

1,224

(838)

3,005

Deferred - net

650

168

230

Total federal and non-U.S.

1,319

(156)

3,403

State

340

110

461

Total income taxes

1,659

(46)

3,864

6,182

6,271

6,646

Other taxes and duties included in production and manufacturing expenses

776

581

1,663

1,001

699

915

Other taxes and duties included in SG&A expenses

201

197

209

Total other taxes and duties

1,978

1,477

2,787

9,819

7,702

13,297

Non-U.S. [Member]

Total federal and non-U.S.

Current

21,093

15,830

31,377

Deferred - net

(1,191)

(665)

1,289

19,902

15,165

32,666

Total income taxes

19,902

15,165

32,666

22,365

19,665

27,862

Other taxes and duties included in production and manufacturing expenses

35,342

34,238

40,056

1,237

1,318

1,720

Other taxes and duties included in SG&A expenses

570

538

660

Total other taxes and duties

37,149

36,094

42,436

$ 79,416

$ 70,924

$ 102,964

[1]	Sales and other operating revenue includes sales-based taxes of $28,547 million for 2010, $25,936 million for 2009 and $34,508 million for 2008.

Income, Sales-Based and Other Taxes (Income Taxes Charged/Credited Directly to Equity) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Cumulative foreign exchange translation adjustment	$ (42)	$ (247)	$ 360
Net actuarial loss/(gain)	553	(94)	3,361
Amortization of actuarial loss/(gain)	(609)	(649)	(317)
Prior service cost	92	20	4
Amortization of prior service cost	(45)	(43)	(51)
Foreign exchange rate changes	44	175	(274)
Total postretirement benefits reserves adjustment	35	(591)	2,723
Other components of equity	$ 246	$ 140	$ 315

Income, Sales-Based, and Other Taxes (Reconciliation Between Income Tax Expense and Theoretical U.S. Tax) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Income, Sales Based And Other Taxes
United States income before income taxes	$ 7,711	$ 2,576	$ 10,152
Non-U.S. income before income taxes	45,248	32,201	73,245
Total income before taxes	52,959	34,777	83,397
Theoretical tax	18,536	12,172	29,189
Effect of equity method of accounting	(3,737)	(2,500)	(3,878)
Non-U.S. taxes in excess of theoretical U.S. tax	7,293	5,948	10,188
U.S. tax on non-U.S. operations	46	32	230
State taxes, net of federal tax benefit	221	72	300
Other U.S.	(798)	(605)	501
Total income tax expense	21,561	15,119	36,530
ExxonMobil share of equity company income taxes	4,058	2,489	4,001
Total income taxes	25,619	17,608	40,531
Net income including noncontrolling interests	31,398	19,658	46,867
Total income before taxes	$ 57,017	$ 37,266	$ 87,398
Effective income tax rate	45.00%	47.00%	46.00%

Income, Sales-Based and Other Taxes (Deferred Income Taxes Assets and Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009
Statement [Line Items]
Property, plant and equipment	$ 42,657	$ 29,931
Other liabilities	4,278	4,102
Total deferred tax liabilities	46,935	34,033
Pension and other postretirement benefits	(5,634)	(5,442)
Asset retirement obligations	(4,461)	(3,978)
Tax loss carryforwards	(3,243)	(3,693)
Other assets	(6,070)	(4,700)
Total deferred tax assets	(19,408)	(17,813)
Asset valuation allowances	1,183	1,495
Net deferred tax liabilities	$ 28,710	$ 17,715

Income, Sales-Based and Other Taxes (Deferred Income Tax (Assets) and Liabilities by Balance Sheet Classification) (Details) - USD ($) $ in Millions	Dec. 31, 2010	Dec. 31, 2009
Statement [Line Items]
Other current assets	$ (5,269)	$ (5,175)
Other assets, including intangibles, net	(8,640)	(7,307)
Accounts payable and accrued liabilities	50,034	41,275
Deferred income tax liabilities	35,150	23,148
Net deferred tax liabilities	28,710	17,715
Deferred Taxes [Member]
Statement [Line Items]
Other current assets	(3,359)	(3,322)
Other assets, including intangibles, net	(3,527)	(2,263)
Accounts payable and accrued liabilities	446	152
Deferred income tax liabilities	35,150	23,148
Net deferred tax liabilities	$ 28,710	$ 17,715

Income, Sales-Based and Other Taxes (Unrecognized Tax Benefits) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Statement [Line Items]
Balance at January 1	$ 4,725	$ 4,976	$ 5,232
Additions based on current year's tax positions	830	547	656
Additions for prior years' tax positions	620	262	294
Reductions for prior years' tax positions	(505)	(594)	(328)
Reductions due to lapse of the statute of limitations	(534)		(27)
Settlements with tax authorities	(999)	(592)	(681)
Foreign exchange effects/other	11	126	(170)
Balance at December 31	$ 4,148	$ 4,725	$ 4,976

Income, Sales-Based and Other Taxes (Remaining Tax Years Subject to Examination by Major Tax Jurisdiction) (Details)	12 Months Ended
	Dec. 31, 2010
Abu Dhabi [Member]
Statement [Line Items]
Open Tax Years by Major Tax Jurisdiction	2000 - 2010
Angola [Member]
Statement [Line Items]
Open Tax Years by Major Tax Jurisdiction	2007 - 2010
Australia [Member]
Statement [Line Items]
Open Tax Years by Major Tax Jurisdiction	2000 - 2010
Canada [Member]
Statement [Line Items]
Open Tax Years by Major Tax Jurisdiction	1994 - 2010
Equatorial Guinea [Member]
Statement [Line Items]
Open Tax Years by Major Tax Jurisdiction	2005 - 2010
Germany [Member]
Statement [Line Items]
Open Tax Years by Major Tax Jurisdiction	1999 - 2010
Japan [Member]
Statement [Line Items]
Open Tax Years by Major Tax Jurisdiction	2003 - 2010
Malaysia [Member]
Statement [Line Items]
Open Tax Years by Major Tax Jurisdiction	2004 - 2010
Nigeria [Member]
Statement [Line Items]
Open Tax Years by Major Tax Jurisdiction	1998 - 2010
Norway [Member]
Statement [Line Items]
Open Tax Years by Major Tax Jurisdiction	2000 - 2010
United Kingdom [Member]
Statement [Line Items]
Open Tax Years by Major Tax Jurisdiction	2004 - 2010
United States [Member]
Statement [Line Items]
Open Tax Years by Major Tax Jurisdiction	1991 - 1996
Second open tax years by major tax jurisdiction	1998 - 2000
Third open tax years by major tax jurisdiction	2004 - 2010

Acquisition of XTO Energy Inc. (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2010 USD ($)
Statement [Line Items]
Business acquisition, effective date of acquisition	2010/06/25
Exchange ratio, number of common ExxonMobil shares converted from each share of XTO common stock	0.7098
Transaction costs related to merger	$ 18

Acquisition of XTO Energy Inc. (Components of Consideration Transferred in Merger of XTO Energy Inc.) (Details) - USD ($)
$ / shares in Units, shares in Millions, $ in Millions

1 Months Ended

Jun. 25, 2010

Dec. 31, 2010

Consideration attributable to stock issued

^[1],[2]

$ 24,480

Consideration attributable to converted stock options

^[2]

179

Total consideration transferred

$ 24,659

Common stock fair market value per share

$ 59.10

Stock issued during period, shares, treasury stock reissued

416

Stock issued during period, value, treasury stock reissued

$ 21,139

Excess fair value over cost of treasury stock issued used in XTO acquisition

$ 3,520

[1]

[2]

The portion of the fair value of XTO converted stock-based awards attributable to pre-merger employee service was part of consideration. The remaining fair value of the awards will be recognized in future periods over the requisite service period.

Acquisition of XTO Energy Inc. (Recording of Assets Acquired and Liabilities Assumed) (Details)
$ in Millions

1 Months Ended

12 Months Ended

Jun. 25, 2010

USD ($)

Dec. 31, 2010

Cash and cash equivalents

$ 47

Notes and accounts receivable

925

Inventories

170

Other current assets

^[1]

911

Investments, advances and long-term receivables

Property, plant and equipment

^[2]

47,300

Identifiable intangible assets

^[3]

493

Goodwill

^[4]

Other assets

^[1]

Total assets acquired

50,012

Notes and loans payable

^[5]

1,026

Accounts payable and accrued liabilities

^[1],[6]

1,788

Income taxes payable

(199)

^[5]

10,574