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Income from equity affiliates

^[1],[2]

$ 394,105

$ 420,836

$ 451,509

13,323

13,927

15,010

Other income

4,511

3,492

14,162

Total revenues and other income

411,939

438,255

480,681

Costs and other deductions

Crude oil and product purchases

225,972

244,156

263,535

Production and manufacturing expenses

40,859

40,525

38,521

Selling, general and administrative expenses

12,598

12,877

13,877

Depreciation and depletion

17,297

17,182

15,888

Exploration expenses, including dry holes

1,669

1,976

1,840

286

327

^[2]

29,342

30,589

32,409

Total costs and other deductions

32,286

33,230

35,558

360,309

380,544

401,955

Income before income taxes

51,630

57,711

78,726

Net income including noncontrolling interests

18,015

24,263

31,045

33,615

33,448

47,681

Net income attributable to noncontrolling interests

1,095

868

2,801

Net income attributable to ExxonMobil

$ 32,520

$ 32,580

$ 44,880

Earnings per common share (dollars)

^[3]

$ 7.6

$ 7.37

$ 9.7

Earnings per common share - assuming dilution (dollars)

$ 7.6

$ 7.37

$ 9.7

[1]	Sales and other operating revenue includes sales-based taxes of $29,342 million for 2014, $30,589 million for 2013 and $32,409 million for 2012. See Note 1, Summary of Accounting Policies.
[2]	Sales and other operating revenue includes sales-based taxes of $29,342 million for 2014, $30,589 million for 2013 and $32,409 million for 2012.
[3]	The earnings per common share and earnings per common share - assuming dilution are the same in each period shown.

Consolidated Statement Of Income (Parenthetical) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Consolidated Statement Of Income [Abstract]

Sales-based taxes included in sales and other operating revenue

^[1]

$ 29,342

$ 30,589

$ 32,409

[1]	Sales and other operating revenue includes sales-based taxes of $29,342 million for 2014, $30,589 million for 2013 and $32,409 million for 2012.

Consolidated Statement Of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Consolidated Statement Of Comprehensive Income [Abstract]
Net income including noncontrolling interests	$ 33,615	$ 33,448	$ 47,681
Other comprehensive income (net of income taxes)
Foreign exchange translation adjustment	(5,847)	(3,620)	920
Adjustment for foreign exchange translation (gain)/loss included in net income	152	(23)	(4,352)
Postretirement benefits reserves adjustment (excluding amortization)	(4,262)	3,174	(3,574)
Amortization and settlement of postretirement benefits reserves adjustment included in net periodic benefit costs	1,111	1,820	2,395
Unrealized change in fair value of stock investments	(63)
Realized (gain)/ loss from stock investments included in net income	3
Total other comprehensive income	(8,906)	1,351	(4,611)
Comprehensive income including noncontrolling interests	24,709	34,799	43,070
Comprehensive income attributable to noncontrolling interests	421	760	1,251
Comprehensive income attributable to ExxonMobil	$ 24,288	$ 34,039	$ 41,819

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2014	Dec. 31, 2013
Current assets
Cash and cash equivalents	$ 4,616	$ 4,644
Cash and cash equivalents - restricted	42	269
Notes and accounts receivable, less estimated doubtful amounts	28,009	33,152
Inventories
Crude oil, products and merchandise	12,384	12,117
Materials and supplies	4,294	4,018
Other current assets	3,565	5,108
Total current assets	52,910	59,308
Investments, advances and long-term receivables	35,239	36,328
Property, plant and equipment, at cost, less accumulated depreciation and depletion	252,668	243,650
Other assets, including intangibles, net	8,676	7,522
Total assets	349,493	346,808
Current liabilities
Notes and loans payable	17,468	15,808
Accounts payable and accrued liabilities	42,227	48,085
Income taxes payable	4,938	7,831
Total current liabilities	64,633	71,724
Long-term debt	11,653	6,891
Postretirement benefits reserves	25,802	20,646
Deferred income tax liabilities	39,230	40,530
Long-term obligations to equity companies	5,325	4,742
Other long-term obligations	21,786	21,780
Total liabilities	168,429	166,313
Commitments and contingencies (Note 16)
Equity
Common stock without par value (9,000 million shares authorized, 8,019 million shares issued)	10,792	10,077
Earnings reinvested	408,384	387,432
Accumulated other comprehensive income	(18,957)	(10,725)
Common stock held in treasury (3,818 million shares in 2014 and 3,684 million shares in 2013)	(225,820)	(212,781)
ExxonMobil share of equity	174,399	174,003
Noncontrolling interests	6,665	6,492
Total equity	181,064	180,495
Total liabilities and equity	$ 349,493	$ 346,808

Consolidated Balance Sheet (Parenthetical) - $ / shares	Dec. 31, 2014	Dec. 31, 2013
Consolidated Balance Sheet [Abstract]
Common stock, without par value
Common stock, shares authorized	9,000,000,000	9,000,000,000
Common stock, shares issued	8,019,000,000	8,019,000,000
Common stock held in treasury, shares	3,818,000,000	3,684,000,000

Consolidated Statement Of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash flows from operating activities
Net income including noncontrolling interests	$ 33,615	$ 33,448	$ 47,681
Adjustments for noncash transactions
Depreciation and depletion	17,297	17,182	15,888
Deferred income tax charges/(credits)	1,540	754	3,142
Postretirement benefits expense in excess of/(less than) net payments	524	2,291	(315)
Other long-term obligation provisions in excess of/(less than) payments	1,404	(2,566)	1,643
Dividends received greater than/(less than) equity in current earnings of equity companies	(358)	3	(1,157)
Changes in operational working capital, excluding cash and debt
Reduction/(increase) - Notes and accounts receivable	3,118	(305)	(1,082)
Reduction/(increase) - Inventories	(1,343)	(1,812)	(1,873)
Reduction/(increase) - Other current assets	(68)	(105)	(42)
Increase/(reduction) - Accounts and other payables	(6,639)	(2,498)	3,624
Net (gain) on asset sales	(3,151)	(1,828)	(13,018)
All other items - net	(823)	350	1,679
Net cash provided by operating activities	45,116	44,914	56,170
Cash flows from investing activities
Additions to property, plant and equipment	(32,952)	(33,669)	(34,271)
Proceeds associated with sales of subsidiaries, property, plant and equipment, and sales and returns of investments	4,035	2,707	7,655
Decrease/(increase) in restricted cash and cash equivalents	227	72	63
Additional investments and advances	(1,631)	(4,435)	(598)
Collection of advances	3,346	1,124	1,550
Net cash used in investing activities	(26,975)	(34,201)	(25,601)
Cash flows from financing activities
Additions to long-term debt	5,731	345	995
Reductions in long-term debt	(69)	(13)	(147)
Additions to short-term debt		16	958
Reductions in short-term debt	(745)	(756)	(4,488)
Additions/(reductions) in debt with three months or less maturity	2,049	12,012	(226)
Cash dividends to ExxonMobil shareholders	(11,568)	(10,875)	(10,092)
Cash dividends to noncontrolling interests	(248)	(304)	(327)
Changes in noncontrolling interests		(1)	204
Tax benefits related to stock-based awards	115	48	130
Common stock acquired	(13,183)	(15,998)	(21,068)
Common stock sold	30	50	193
Net cash used in financing activities	(17,888)	(15,476)	(33,868)
Effects of exchange rate changes on cash	(281)	(175)	217
Increase/(decrease) in cash and cash equivalents	(28)	(4,938)	(3,082)
Cash and cash equivalents at beginning of year	4,644	9,582	12,664
Cash and cash equivalents at end of year	$ 4,616	$ 4,644	$ 9,582

Consolidated Statement Of Changes In Equity - USD ($) $ in Millions	Total	ExxonMobil Share Of Common Stock [Member]	ExxonMobil Share Of Earnings Reinvested [Member]	ExxonMobil Share Of Accumulated Other Comprehensive Income [Member]	ExxonMobil Share Of Common Stock Held In Treasury [Member]	ExxonMobil Share Of Equity [Member]	Noncontrolling Interests [Member]	Common Stock Outstanding [Member]
Balance at Dec. 31, 2011	$ 160,744	$ 9,512	$ 330,939	$ (9,123)	$ (176,932)	$ 154,396	$ 6,348
Balance (in shares) - issued at Dec. 31, 2011		8,019,000,000
Balance (in shares) - in treasury at Dec. 31, 2011					(3,285,000,000)
Balance (in shares) - outstanding at Dec. 31, 2011								4,734,000,000
Amortization of stock-based awards	806	$ 806				806
Tax benefits related to stock-based awards	178	178				178
Other	(2,284)	(843)				(843)	(1,441)
Net income for the year	47,681		44,880			44,880	2,801
Dividends - common shares (company)			(10,092)			(10,092)
Dividends - common shares (NCI)							(327)
Dividends - common shares (total)	(10,419)
Other comprehensive income	(4,611)			(3,061)		(3,061)	(1,550)
Acquisitions, at cost (company)					$ (21,068)	(21,068)
Acquisitions, at cost (NCI)							(34)
Acquisitions, at cost (total)	(21,102)
Dispositions	667				$ 667	667
Acquisitions (in shares)					(244,000,000)			(244,000,000)
Dispositions (in shares)					12,000,000			12,000,000
Balance at Dec. 31, 2012	171,660	$ 9,653	365,727	(12,184)	$ (197,333)	165,863	5,797
Balance (in shares) - issued at Dec. 31, 2012		8,019,000,000
Balance (in shares) - in treasury at Dec. 31, 2012					(3,517,000,000)
Balance (in shares) - outstanding at Dec. 31, 2012								4,502,000,000
Amortization of stock-based awards	761	$ 761				761
Tax benefits related to stock-based awards	162	162				162
Other	(259)	(499)				(499)	240
Net income for the year	33,448		32,580			32,580	868
Dividends - common shares (company)			(10,875)			(10,875)
Dividends - common shares (NCI)							(304)
Dividends - common shares (total)	(11,179)
Other comprehensive income	1,351			1,459		1,459	(108)
Acquisitions, at cost (company)					$ (15,998)	(15,998)
Acquisitions, at cost (NCI)							(1)
Acquisitions, at cost (total)	(15,999)
Dispositions	550				$ 550	550
Acquisitions (in shares)					(177,000,000)			(177,000,000)
Dispositions (in shares)					10,000,000			10,000,000
Balance at Dec. 31, 2013	$ 180,495	$ 10,077	387,432	(10,725)	$ (212,781)	174,003	6,492
Balance (in shares) - issued at Dec. 31, 2013	8,019,000,000	8,019,000,000
Balance (in shares) - in treasury at Dec. 31, 2013	3,684,000,000				(3,684,000,000)
Balance (in shares) - outstanding at Dec. 31, 2013								4,335,000,000
Amortization of stock-based awards	$ 780	$ 780				780
Tax benefits related to stock-based awards	49	49				49
Other	(114)	(114)				(114)
Net income for the year	33,615		32,520			32,520	1,095
Dividends - common shares (company)			(11,568)			(11,568)
Dividends - common shares (NCI)							(248)
Dividends - common shares (total)	(11,816)
Other comprehensive income	(8,906)			(8,232)		(8,232)	(674)
Acquisitions, at cost (company)					$ (13,183)	(13,183)
Acquisitions, at cost (total)	(13,183)
Dispositions	144				$ 144	144
Acquisitions (in shares)					(136,000,000)			(136,000,000)
Dispositions (in shares)					2,000,000			2,000,000
Balance at Dec. 31, 2014	$ 181,064	$ 10,792	$ 408,384	$ (18,957)	$ (225,820)	$ 174,399	$ 6,665
Balance (in shares) - issued at Dec. 31, 2014	8,019,000,000	8,019,000,000
Balance (in shares) - in treasury at Dec. 31, 2014	3,818,000,000				(3,818,000,000)
Balance (in shares) - outstanding at Dec. 31, 2014								4,201,000,000

Summary Of Accounting Policies	12 Months Ended
Summary Of Accounting Policies	Dec. 31, 2014
Summary Of Accounting Policies [Abstract]
Summary Of Accounting Policies	1. Summary of Accounting Policies Principles of Consolidation. The Consolidated Financial Statements include the accounts of subsidiaries the Corporation controls. They also include the Corporation’s share of the undivided interest in certain upstream assets, liabilities, revenues and expenses. Amounts representing the Corporation’s interest in entities that it does not control, but over which it exercises significant influence, 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.” Majority ownership is normally the indicator of control that is the basis on which subsidiaries are consolidated. However, certain factors may indicate that a majority-owned investment is not controlled and therefore should be accounted for using the equity method of accounting. These factors occur where the minority shareholders are granted by law or by contract substantive participating rights. These include the right to approve operating policies, expense budgets, financing and investment plans, and management compensation and succession plans. The Corporation’s share of the cumulative foreign exchange translation adjustment for equity method investments is reported in Accumulated Other Comprehensive Income. 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, 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. 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). 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. The gains and losses resulting from changes in the fair value of derivatives are recorded in income. In some cases, the Corporation designates derivatives as fair value hedges, in which case the gains and losses are offset in income by the gains and losses arising from changes in the fair value of the underlying hedged item. 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 and 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. 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. Costs incurred to purchase, lease, or otherwise acquire a property (whether unproved or proved) are capitalized when incurred. Exploratory well costs are carried as an asset 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. Other exploratory expenditures, including geophysical costs and annual lease rentals, are expensed as incurred. Development costs including costs of productive wells and development dry holes are capitalized. Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves. Capitalized exploratory drilling and development costs associated with productive depletable extractive properties are amortized using unit-of-production rates 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 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 and are expensed as incurred. 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. 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 and natural gas commodity prices, refining and chemical margins and foreign currency exchange rates. Annual volumes are based on field production profiles, which are also updated annually. Prices for other petroleum and chemical 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. An asset group would be impaired if the undiscounted cash flows were less than its carrying value. Impairments are measured by the amount the carrying value exceeds fair value. 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. Gains on sales of proved and unproved properties are only recognized when there is neither uncertainty about the recovery of costs applicable to any interest retained nor any 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. 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. Asset Retirement Obligations and Environmental Liabilities. The Corporation incurs retirement obligations for certain 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 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 price of the stock at the date of grant and is recognized in income over the requisite service period.

Accounting Changes	12 Months Ended
Accounting Changes	Dec. 31, 2014
Accounting Changes [Abstract]
Accounting Changes	2. Accounting Changes The Corporation did not adopt authoritative guidance in 2014 that had a material impact on the Corporation’s financial statements. In May 2014, the Financial Accounting Standards Board issued a new standard, Revenue from Contracts with Customers. The standard establishes a single revenue recognition model for all contracts with customers, eliminates industry specific requirements, and expands disclosure requirements. The standard is required to be adopted beginning January 1, 2017. ExxonMobil is evaluating the standard and its effect on the Corporation’s financial statements.

Tabular disclosure of changes in accounting principles, including adoption of new accounting pronouncements, that describes the new methods, amount and effects on financial statement line items.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=28359718&loc=d3e22580-107794

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Direct Effects of a Change in Accounting Principle
-URI http://asc.fasb.org/extlink&oid=6510796

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Indirect Effects of a Change in Accounting Principle
-URI http://asc.fasb.org/extlink&oid=6515603

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 270
-SubTopic 10
-Section 45
-Paragraph 13
-URI http://asc.fasb.org/extlink&oid=6372559&loc=d3e765-108305

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Accounting Change
-URI http://asc.fasb.org/extlink&oid=6503790

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=28359718&loc=d3e22499-107794

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 270
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.10-01.(b)(6))
-URI http://asc.fasb.org/extlink&oid=27015980&loc=d3e46468-122699

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=28359718&loc=d3e22583-107794

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Change in Accounting Principle
-URI http://asc.fasb.org/extlink&oid=6507316

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 270
-SubTopic 10
-Section 45
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=6372559&loc=d3e725-108305

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Retrospective Application
-URI http://asc.fasb.org/extlink&oid=6523989

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 01
-Paragraph b
-Subparagraph 6
-Article 10

Miscellaneous Financial Information [Abstract]

Miscellaneous Financial Information

12 Months Ended

Dec. 31, 2014

Miscellaneous Financial Information

3. Miscellaneous Financial Information

Research and development expenses totaled $971 million in 2014, $1,044 million in 2013 and $1,042 million in 2012.

Net income included before-tax aggregate foreign exchange transaction losses of $225 million, and gains of $155 million and $159 million in 2014, 2013 and 2012, respectively.

In 2014, 2013 and 2012, net income included gains of $187 million, $282 million and $328 million, respectively, attributable to the combined effects of LIFO inventory accumulations and drawdowns. The aggregate replacement cost of inventories was estimated to exceed their LIFO carrying values by $10.6 billion and $21.2 billion at December 31, 2014, and 2013, respectively.

Crude oil, products and merchandise as of year-end 2014 and 2013 consist of the following:

		2014	2013
		(billions of dollars)

Petroleum products		4.1	3.9
Crude oil		4.6	4.7
Chemical products		2.9	2.9
Gas/other		0.8	0.6
	Total	12.4	12.1

Other Comprehensive Income Information

12 Months Ended

Dec. 31, 2014

Other Comprehensive Income Information [Abstract]

Other Comprehensive Income Information

4. Other Comprehensive Income Information

		Cumulative	Post-
		Foreign	retirement	Unrealized
		Exchange	Benefits	Change in
ExxonMobil Share of Accumulated Other		Translation	Reserves	Stock
Comprehensive Income		Adjustment	Adjustment	Investments	Total
		(millions of dollars)
Balance as of December 31, 2011		4,168	(13,291)	-	(9,123)
Current period change excluding amounts reclassified
	from accumulated other comprehensive income	842	(3,402)	-	(2,560)
Amounts reclassified from accumulated other
	comprehensive income	(2,600)	2,099	-	(501)
Total change in accumulated other comprehensive income		(1,758)	(1,303)	-	(3,061)
Balance as of December 31, 2012		2,410	(14,594)	-	(12,184)

Balance as of December 31, 2012		2,410	(14,594)	-	(12,184)
Current period change excluding amounts reclassified
	from accumulated other comprehensive income	(3,233)	2,963	-	(270)
Amounts reclassified from accumulated other
	comprehensive income	(23)	1,752	-	1,729
Total change in accumulated other comprehensive income		(3,256)	4,715	-	1,459
Balance as of December 31, 2013		(846)	(9,879)	-	(10,725)

Balance as of December 31, 2013		(846)	(9,879)	-	(10,725)
Current period change excluding amounts reclassified
	from accumulated other comprehensive income	(5,258)	(4,132)	(63)	(9,453)
Amounts reclassified from accumulated other
	comprehensive income	152	1,066	3	1,221
Total change in accumulated other comprehensive income		(5,106)	(3,066)	(60)	(8,232)
Balance as of December 31, 2014		(5,952)	(12,945)	(60)	(18,957)

Amounts Reclassified Out of Accumulated Other
Comprehensive Income - Before-tax Income/(Expense)		2014	2013	2012
		(millions of dollars)
Foreign exchange translation gain/(loss) included in net income
	(Statement of Income line: Other income)	(152)	23	4,352
Amortization and settlement of postretirement benefits reserves
	adjustment included in net periodic benefit costs (1)	(1,571)	(2,616)	(3,621)
Realized change in fair value of stock investments included in net income
	(Statement of Income line: Other income)	(5)	-	-

(1) These accumulated other comprehensive income components are included in the computation of net periodic pension cost. (See Note 17 – Pension and Other Postretirement Benefits for additional details.)

Income Tax (Expense)/Credit For
Components of Other Comprehensive Income		2014	2013	2012
		(millions of dollars)
Foreign exchange translation adjustment		292	218	(236)
Postretirement benefits reserves adjustment (excluding amortization)		2,009	(1,540)	1,619
Amortization and settlement of postretirement benefits reserves
	adjustment included in net periodic benefit costs	(460)	(796)	(1,226)
Unrealized change in fair value of stock investments		34	-	-
Realized change in fair value of stock investments included in net income		(2)	-	-
Total		1,873	(2,118)	157

The entire disclosure for comprehensive income, which includes, but is not limited to, 1) the amount of income tax expense or benefit allocated to each component of other comprehensive income, including reclassification adjustments, 2) the reclassification adjustments for each classification of other comprehensive income and 3) the ending accumulated balances for each component of comprehensive income.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=36458714&loc=d3e689-108580

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=36458714&loc=SL7669619-108580

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=36458714&loc=d3e640-108580

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 17
-URI http://asc.fasb.org/extlink&oid=36458714&loc=d3e716-108580

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 16
-URI http://asc.fasb.org/extlink&oid=36458714&loc=d3e709-108580

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.3-04)
-URI http://asc.fasb.org/extlink&oid=27012166&loc=d3e187085-122770

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 11
-URI http://asc.fasb.org/extlink&oid=36458714&loc=d3e637-108580

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 14
-URI http://asc.fasb.org/extlink&oid=36458714&loc=d3e681-108580

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Reclassification Adjustments
-URI http://asc.fasb.org/extlink&oid=6522872

Additional Working Capital Information [Abstract]

Cash Flow Information

12 Months Ended

Dec. 31, 2014

Cash Flow Information [Abstract]

Cash Flow Information

5. 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.

For 2014, the “Net (gain) on asset sales” on the Consolidated Statement of Cash Flows includes before-tax gains from the sale of Hong Kong power operations, additional proceeds related to the 2013 sale of a partial interest in Iraq, the sale of Downstream affiliates in the Caribbean and the sale or exchange of Upstream properties in the U.S., Canada, and Malaysia. For 2013, the amount includes before-tax gains from the sale of a partial interest in Iraq, the sale of Downstream affiliates in the Caribbean and the sale of service stations. For 2012, the amount includes before-tax gains related to the Japan restructuring, the sale of an Upstream property in Angola, exchanges of Upstream properties, the sale of U.S. service stations and the sale of Downstream affiliates in Malaysia and Switzerland. These gains are reported in “Other income” on the Consolidated Statement of Income.

In 2014, ExxonMobil completed asset exchanges, primarily non-cash transactions, of approximately $1.2 billion. This amount is not included in the “Sales of subsidiaries, investments, and property, plant and equipment” or the “Additions to property, plant and equipment” lines on the Statement of Cash Flows.

In 2012, the Corporation’s interest in a cost company was redeemed. As part of the redemption, a variable note due in 2035 issued by Mobil Services (Bahamas) Ltd. was assigned to a consolidated ExxonMobil affiliate. This note is no longer classified as third party long-term debt. This assignment did not result in a “Reduction in long-term debt” on the Statement of Cash Flows.

In 2012, ExxonMobil completed asset exchanges, primarily noncash transactions, of approximately $1 billion. This amount is not included in the “Sales of subsidiaries, investments, and property, plant and equipment” or the “Additions to property, plant and equipment” lines on the Statement of Cash Flows.

Additional Working Capital Information

12 Months Ended

Dec. 31, 2014

Additional Working Capital Information

6. Additional Working Capital Information

			Dec. 31	Dec. 31
			2014	2013
			(millions of dollars)
Notes and accounts receivable
	Trade, less reserves of $113 million and $112 million		18,541	25,993
	Other, less reserves of $48 million and $28 million		9,468	7,159
		Total	28,009	33,152

Notes and loans payable
	Bank loans		473	723
	Commercial paper		16,225	14,051
	Long-term debt due within one year		770	1,034
		Total	17,468	15,808

Accounts payable and accrued liabilities
	Trade payables		25,286	30,920
	Payables to equity companies		6,589	6,587
	Accrued taxes other than income taxes		3,290	3,883
	Other		7,062	6,695
		Total	42,227	48,085

The Corporation has short-term committed lines of credit of $6.3 billion which were unused as of December 31, 2014. These lines are available for general corporate purposes.

The weighted-average interest rate on short-term borrowings outstanding was 0.3 percent and 0.4 percent at December 31, 2014, and 2013, respectively.

Equity Company Information

12 Months Ended

Dec. 31, 2014

Equity Company Information [Abstract]

Equity Company Information

7. 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 oil and gas exploration and production, natural gas marketing, and refining operations in North America; natural gas exploration, production and distribution, and downstream operations in Europe; and exploration, production, liquefied natural gas (LNG) operations, refining operations, petrochemical manufacturing, and fuel sales in Asia. Also included are several refining, petrochemical manufacturing, and marketing ventures.

The Corporation’s ownership in these ventures is in the form of shares in corporate joint ventures as well as interests in partnerships. Differences between the company’s carrying value of an equity investment and its underlying equity in the net assets of the affiliate are assigned to the extent practicable to specific assets and liabilities based on the company’s analysis of the factors giving rise to the difference. The amortization of this difference, as appropriate, is included in “income from equity affiliates.”

The share of total equity company revenues from sales to ExxonMobil consolidated companies was 14 percent, 13 percent and 16 percent in the years 2014, 2013 and 2012, respectively.

In 2013 and 2014, the Corporation and Rosneft established various entities to conduct exploration and research activities. Periods of disproportionate funding will result in the Corporation recognizing, during the early phases of the projects, an investment that is larger than its equity share in these entities. These joint ventures are considered Variable Interest Entities. However, since the Corporation is not the primary beneficiary of these entities, the joint ventures are reported as equity companies. In 2014, the European Union and United States imposed sanctions relating to the Russian energy sector. In compliance with the sanctions and all general and specific licenses, prohibited activities involving offshore Russia in the Black Sea, Arctic regions, and onshore western Siberia have been wound down. The Corporation's maximum exposure to loss from these joint ventures as of December 31, 2014, is $1.0 billion.

		2014			2013			2012
Equity Company			ExxonMobil			ExxonMobil			ExxonMobil
Financial Summary		Total		Share	Total		Share	Total		Share
		(millions of dollars)

Total revenues		183,708		55,855	236,161		68,084	224,953		67,572
Income before income taxes		65,549		19,014	69,454		19,999	69,411		20,882
Income taxes		20,520		5,684	21,618		6,069	20,703		5,868
	Income from equity affiliates	45,029		13,330	47,836		13,930	48,708		15,014

Current assets		49,905		16,802	62,398		19,545	59,612		18,483
Long-term assets		110,754		33,619	116,450		35,695	111,131		33,798
	Total assets	160,659		50,421	178,848		55,240	170,743		52,281
Current liabilities		37,333		11,472	54,550		15,243	49,698		14,265
Long-term liabilities		66,231		19,470	68,857		20,873	68,855		19,715
	Net assets	57,095		19,479	55,441		19,124	52,190		18,301

A list of significant equity companies as of December 31, 2014, together with the Corporation’s percentage ownership interest, is detailed below:

		Percentage
		Ownership
		Interest
	Upstream
	Aera Energy LLC	48
	BEB Erdgas und Erdoel GmbH & Co. KG	50
	Cameroon Oil Transportation Company S.A.	41
	Cross Timbers Energy, LLC	50
	Golden Pass LNG Terminal LLC	18
	Karmorneftegaz Holding SARL	33
	Marine Well Containment Company LLC	10
	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.	71

	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
	Infineum USA L.P.	50
	Saudi Yanbu Petrochemical Co.	50

Investments, Advances And Long-Term Receivables

12 Months Ended

Dec. 31, 2014

Investments, Advances And Long-Term Receivables [Abstract]

Investments, Advances And Long-Term Receivables

8. Investments, Advances and Long-Term Receivables

			Dec. 31,	Dec. 31,
			2014	2013
			(millions of dollars)
Companies carried at equity in underlying assets
	Investments		20,017	19,619
	Advances		9,818	10,476
		Total equity company investments and advances	29,835	30,095
Companies carried at cost or less and stock investments carried at fair value			526	115
Long-term receivables and miscellaneous investments at cost or less, net of reserves
	of $2,662 million and $2,938 million		4,878	6,118
		Total	35,239	36,328

Property, Plant And Equipment And Asset Retirement Obligations

12 Months Ended

Dec. 31, 2014

Property, Plant And Equipment And Asset Retirement Obligations [Abstract]

Property, Plant And Equipment And Asset Retirement Obligations

9. Property, Plant and Equipment and Asset Retirement Obligations

		December 31, 2014		December 31, 2013
Property, Plant and Equipment		Cost	Net	Cost	Net
		(millions of dollars)

Upstream		347,170	205,308	336,359	197,554
Downstream		53,327	22,639	54,456	23,219
Chemical		30,717	14,918	29,487	13,965
Other		15,575	9,803	14,215	8,912
	Total	446,789	252,668	434,517	243,650

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 $194,121 million at the end of 2014 and $190,867 million at the end of 2013. Interest capitalized in 2014, 2013 and 2012 was $344 million, $309 million and $506 million, respectively.

Asset Retirement Obligations

The Corporation incurs retirement obligations for certain 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. In the estimation of fair value, the Corporation uses assumptions and judgments regarding such factors as the existence of a legal obligation for an asset retirement obligation; technical assessments of the assets; estimated amounts and timing of settlements; discount rates; and inflation rates. Asset retirement obligations incurred in the current period were Level 3 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:

		2014	2013
		(millions of dollars)

Beginning balance		12,988	11,973
	Accretion expense and other provisions	871	785
	Reduction due to property sales	(151)	(97)
	Payments made	(724)	(664)
	Liabilities incurred	122	603
	Foreign currency translation	(908)	(344)
	Revisions	1,226	732
Ending balance		13,424	12,988

Accounting For Suspended Exploratory Well Costs

12 Months Ended

Dec. 31, 2014

Accounting For Suspended Exploratory Well Costs [Abstract]

Accounting For Suspended Exploratory Well Costs

10. Accounting for Suspended Exploratory Well Costs

The Corporation continues capitalization of exploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and the Corporation is making sufficient progress assessing the reserves and the economic and operating viability of the project. The term “project” as used in this report can refer to a variety of different activities and does not necessarily have the same meaning as in any government payment transparency reports.

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:

			2014	2013	2012
			(millions of dollars)

Balance beginning at January 1			2,707	2,679	2,881
	Additions pending the determination of proved reserves		1,095	293	868
	Charged to expense		(28)	(52)	(95)
	Reclassifications to wells, facilities and equipment based on the
		determination of proved reserves	(160)	(107)	(631)
	Divestments/Other		(27)	(106)	(344)
Ending balance at December 31			3,587	2,707	2,679
Ending balance attributed to equity companies included above			645	13	3

Period end capitalized suspended exploratory well costs:

			2014	2013	2012
			(millions of dollars)

Capitalized for a period of one year or less			1,095	293	866
	Capitalized for a period of between one and five years		1,659	1,705	1,176
	Capitalized for a period of between five and ten years		544	470	401
	Capitalized for a period of greater than ten years		289	239	236
Capitalized for a period greater than one year - subtotal			2,492	2,414	1,813
		Total	3,587	2,707	2,679

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.

			2014	2013	2012
Number of projects with first capitalized well drilled in the preceding 12 months			8	8	10
Number of projects that have exploratory well costs capitalized for a period
	of greater than 12 months		53	50	45
		Total	61	58	55

Of the 53 projects that have exploratory well costs capitalized for a period greater than 12 months as of December 31, 2014, 15 projects have drilling in the preceding 12 months or exploratory activity planned in the next two years, while the remaining 38 projects are those with completed exploratory activity progressing toward development. The table below provides additional detail for those 38 projects, which total $1,035 million.

			Years
		Dec. 31,	Wells
Country/Project		2014	Drilled	Comment
	(millions of dollars)
Angola
- Kaombo Split Hub Phase 2		20	2005 - 2006	Evaluating development plan to tie into planned production facilities.
- Perpetua-Zinia-Acacia		15	2008 - 2009	Oil field near Pazflor development, awaiting capacity in existing/planned infrastructure.
Australia
- East Pilchard		8	2001	Gas field near Kipper/Tuna development, awaiting capacity in existing/planned
				infrastructure.
- SE Longtom		12	2010	Gas field near Tuna development, awaiting capacity in existing/planned infrastructure.
- SE Remora		38	2010	Gas field near Marlin development, awaiting capacity in existing/planned infrastructure.
Indonesia
- Alas Tua West		16	2010	Evaluating development plan to tie into planned production facilities.
- Cepu Gas		28	2008 - 2011	Development activity under way, while continuing commercial discussions with the
				government.
- Kedung Keris		11	2011	Evaluating development plan to tie into planned production facilities.
- Natuna		118	1981 - 1983	Development activity under way, while continuing discussions with the government
				on contract terms pursuant to executed Heads of Agreement.
Kazakhstan
- Kairan		53	2004 - 2007	Evaluating commercialization and field development alternatives, while continuing
				discussions with the government regarding the development plan.
Malaysia
- Besar		18	1992 - 2010	Gas field off the east coast of Malaysia; progressing development plan.
- Bindu		2	1995	Awaiting capacity in existing/planned infrastructure.
Nigeria
- Bolia		15	2002 - 2006	Evaluating development plan, while continuing discussions with the government
				regarding regional hub strategy.
- Bosi		79	2002 - 2006	Development activity under way, while continuing discussions with the government
				regarding development plan.
- Bosi Central		16	2006	Development activity under way, while continuing discussions with the government
				regarding development plan.
- Erha Northeast		26	2008	Evaluating development plan for tieback to existing production facilities.
- Owowo		50	2009 - 2012	Continuing discussions with the government regarding contract terms.
- Pegi		32	2009	Awaiting capacity in existing/planned infrastructure.
- Satellite Field		12	2013	Evaluating development plan to tie into planned production facilities.
Development Phase 2
- Other (4 projects)		14	2002	Evaluating and pursuing development of several additional discoveries.
Norway
- Gamma		15	2008 - 2009	Evaluating development plan for tieback to existing production facilities.
- Lavrans		18	1995 - 1999	Evaluating development plan, awaiting capacity in existing Kristin production facility.
- Other (7 projects)		29	2008 - 2013	Evaluating development plans, including potential for tieback to existing production
				facilities.
Papua New Guinea
- Juha		28	2007	Progressing development plans to tie into existing LNG facilities.
- P'nyang		58	2012	Evaluating development alternatives to tie into existing/planned infrastructure.
Republic of Congo
- Mer Tres Profonde Sud		56	2000 - 2007	Evaluating development alternatives, while continuing discussions with the government
				regarding development plan.
United Kingdom
- Phyllis		8	2004	Evaluating development plan for tieback to existing production facilities.
United States
- Hadrian North		209	2010 - 2013	Evaluating development plan to tie into existing production facilities.
- Tip Top		31	2009	Evaluating development concept and requisite facility upgrades.
Total 2014 (38 projects)		1,035

Leased Facilities

12 Months Ended

Dec. 31, 2014

Leased Facilities [Abstract]

Leased Facilities

11. Leased Facilities

At December 31, 2014, 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 $6,213 million as indicated in the table. Estimated related rental income from noncancelable subleases is $70 million.

		Related
	Lease Payments	Sublease
	Under Minimum	Rental
	Commitments	Income
	(millions of dollars)

2015	2,034	31
2016	1,379	7
2017	774	6
2018	418	3
2019	312	3
2020 and beyond	1,296	20
Total	6,213	70

Net rental cost under both cancelable and noncancelable operating leases incurred during 2014, 2013 and 2012 were as follows:

	2014	2013	2012
	(millions of dollars)

Rental cost	4,077	3,841	3,851
Less sublease rental income	52	44	44
Net rental cost	4,025	3,797	3,807

Litigation And Other Contingencies [Abstract]

Tabular disclosure of a lessee's leasing arrangements including: (1) the basis on which contingent rental payments are determined, (2) the existence and terms of renewal or purchase options and escalation clauses, (3) restrictions imposed by lease arrangements, such as those concerning dividends, additional debt, and further leasing, (4) rent holidays, rent concessions, or leasehold improvement incentives and unusual provisions or conditions. Disclosure may also include the specific period used to amortize material leasehold improvements made at the inception of the lease or during the lease term. Additionally, for operating leases having initial or remaining noncancelable lease terms in excess of one year: (a) future minimum rental payments required as of the date of the latest balance sheet presented, in the aggregate and for each of the five succeeding fiscal years, (b) the total of minimum rentals to be received in the future under noncancelable subleases as of the date of the latest balance sheet presented, and (c) for all operating leases, rental expense for each period for which an income statement is presented, with separate amounts for minimum rentals, contingent rentals, and sublease rentals. Rental payments under leases with terms of a month or less that were not renewed need not be included.

+ References + Details

Earnings Per Share

12 Months Ended

Dec. 31, 2014

Earnings Per Share [Abstract]

Earnings Per Share

12. Earnings Per Share

	2014	2013	2012
Earnings per common share

Net income attributable to ExxonMobil (millions of dollars)	32,520	32,580	44,880

Weighted average number of common shares outstanding (millions of shares)	4,282	4,419	4,628

Earnings per common share (dollars) (1)	7.60	7.37	9.70

Dividends paid per common share (dollars)	2.70	2.46	2.18

(1) The earnings per common share and earnings per common share - assuming dilution are the same in each period shown.

Financial Instruments And Derivatives	12 Months Ended
Financial Instruments And Derivatives	Dec. 31, 2014
Financial Instruments And Derivatives [Abstract]
Financial Instruments And Derivatives	13. 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, excluding capitalized lease obligations, was $11.7 billion and $6.8 billion at December 31, 2014, and 2013, respectively, as compared to recorded book values of $11.3 billion and $6.5 billion at December 31, 2014, and 2013, respectively. The increase in the estimated fair value and book value of long-term debt reflects the Corporation’s issuance of $5,500 million of long-term debt in the first quarter of 2014. The fair value of long-term debt by hierarchy level at December 31, 2014, is: Level 1 $11,036 million; Level 2 $561 million; and Level 3 $63 million. 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. The estimated fair value of derivative instruments outstanding and recorded on the balance sheet was a net asset of $75 million at year-end 2014 and a net asset of $1 million at year-end 2013. Assets and liabilities associated with derivatives are usually recorded either in “Other current assets” or “Accounts payable and accrued liabilities.” The Corporation’s fair value measurement of its derivative instruments use either Level 1 or Level 2 inputs. The Corporation recognized a before-tax gain or (loss) related to derivative instruments of $110 million, $(7) million and $(23) million during 2014, 2013 and 2012, respectively. Income statement effects associated with derivatives are usually recorded either in “Sales and other operating revenue” or “Crude oil and product purchases.” The Corporation believes 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.

Long-Term Debt

12 Months Ended

Dec. 31, 2014

Long-Term Debt [Abstract]

Long-Term Debt

14. Long-Term Debt

At December 31, 2014, long-term debt consisted of $11,341 million due in U.S. dollars and $312 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 $770 million, which matures within one year and is included in current liabilities. The increase in the book value of long-term debt reflects the Corporation’s issuance of $5,500 million of long-term debt in the first quarter of 2014. The amounts of long-term debt maturing in each of the four years after December 31, 2015, in millions of dollars, are: 2016 – $537; 2017 – $2,993; 2018 – $872; and 2019 – $2,353. At December 31, 2014, the Corporation’s unused long-term credit lines were $0.5 billion.

Summarized long-term debt at year-end 2014 and 2013 are shown in the table below:

			2014	2013
			(millions of dollars)
Exxon Mobil Corporation
	0.921% notes due 2017		1,500	-
	Floating-rate notes due 2017 (1)		750	-
	1.819% notes due 2019		1,750	-
	Floating-rate notes due 2019 (2)		500	-
	3.176% notes due 2024		1,000	-

XTO Energy Inc. (3)
	5.000% senior notes due 2015		-	132
	5.300% senior notes due 2015		-	243
	5.650% senior notes due 2016		207	212
	6.250% senior notes due 2017		477	489
	5.500% senior notes due 2018		383	389
	6.500% senior notes due 2018		474	485
	6.100% senior notes due 2036		199	200
	6.750% senior notes due 2037		309	312
	6.375% senior notes due 2038		236	238

Mobil Producing Nigeria Unlimited (4)
	Variable notes due 2015-2019		399	742

Esso (Thailand) Public Company Ltd. (5)
	Variable notes due 2015-2019		121	177

Mobil Corporation
	8.625% debentures due 2021		249	249

Industrial revenue bonds due 2015-2051 (6)			2,611	2,527
Other U.S. dollar obligations (7)			104	112
Other foreign currency obligations			9	9
Capitalized lease obligations (8)			375	375
		Total long-term debt	11,653	6,891

(1) Average effective interest rate of 0.3% in 2014.

(2) Average effective interest rate of 0.4% in 2014.

(3) Includes premiums of $219 million in 2014 and $271 million in 2013.

(4) Average effective interest rate of 4.5% in 2014 and 4.6% in 2013.

(5) Average effective interest rate of 2.4% in 2014 and 3.3% in 2013.

(6) Average effective interest rate of 0.03% in 2014 and 0.06% in 2013.

(7) Average effective interest rate of 4.2% in 2014 and 4.4% in 2013.

(8) Average imputed interest rate of 7.0% in 2014 and 7.8% in 2013.

Incentive Program

12 Months Ended

Dec. 31, 2014

Incentive Program [Abstract]

Incentive Program

15. 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. 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. The maximum number of shares of stock that may be issued under the 2003 Incentive Program is 220 million. Awards that are forfeited, 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 2014, remaining shares available for award under the 2003 Incentive Program were 108 million.

Restricted Stock and Restricted Stock Units. Awards totaling 9,775 thousand, 9,729 thousand, and 10,017 thousand of restricted (nonvested) common stock and restricted (nonvested) common stock units were granted in 2014, 2013 and 2012, respectively. Compensation expense for these awards is based on the price of the stock at the date of grant and is recognized in income over the requisite service period. Shares for these awards are issued to employees from treasury stock. 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 and units 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 and units in each award vesting after three years and the remaining 50 percent vesting after seven years. Awards granted to a small number of 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.

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.

The following tables summarize information about restricted stock and restricted stock units for the year ended December 31, 2014.

	2014
		Weighted Average
		Grant-Date
Restricted stock and units outstanding	Shares	Fair Value per Share
	(thousands)	(dollars)

Issued and outstanding at January 1	45,207		78.29
2013 award issued in 2014	9,705		94.47
Vested	(10,286)		79.89
Forfeited	(187)		78.89
Issued and outstanding at December 31	44,439		81.45


Value of restricted stock and units	2014	2013	2012
Grant price (dollars)	95.20	94.47	87.24

Value at date of grant:	(millions of dollars)
Restricted stock and units settled in stock	858	843	797
Units settled in cash	73	76	77
Total value	931	919	874

As of December 31, 2014, there was $2,339 million of unrecognized compensation cost related to the nonvested restricted awards. This cost is expected to be recognized over a weighted-average period of 4.5 years. The compensation cost charged against income for the restricted stock and restricted stock units was $831 million, $854 million and $854 million for 2014, 2013 and 2012, respectively. The income tax benefit recognized in income related to this compensation expense was $76 million, $78 million and $79 million for the same periods, respectively. The fair value of shares and units vested in 2014, 2013 and 2012 was $946 million, $1,040 million and $926 million, respectively. Cash payments of $73 million, $67 million and $66 million for vested restricted stock units settled in cash were made in 2014, 2013 and 2012, respectively.

Litigation And Other Contingencies

12 Months Ended

Dec. 31, 2014

Litigation And Other Contingencies

16. 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. For purposes of our contingency disclosures, “significant” includes material matters as well as other matters which management believes should be disclosed. 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 material 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, 2014, for guarantees relating to notes, loans and performance under contracts. Where guarantees for environmental remediation and other similar matters do not include a stated cap, the amounts reflect management’s estimate of the maximum potential exposure.

						Dec. 31, 2014
			Equity Company		Other Third-Party
			Obligations (1)		Obligations		Total
					(millions of dollars)
Guarantees
	Debt-related			3,506		41	3,547
	Other			2,920		3,982	6,902
		Total		6,426		4,023	10,449

(1) ExxonMobil share.

The debt-related guarantees shown above include a $3.4 billion completion guarantee provided to lenders in support of the project financing for the Papua New Guinea Liquefied Natural Gas project. On February 4, 2015, the obligations under this guarantee were terminated per the terms of the loan agreement.

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
		2016-	2020 and
	2015	2019	Beyond		Total
	(millions of dollars)

Unconditional purchase obligations (1)	150	608		337	1,095

(1) Undiscounted obligations of $1,095 million mainly pertain to pipeline throughput agreements and include $433 million of obligations to equity companies. The present value of these commitments, which excludes imputed interest of $168 million, totaled $927 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. On October 9, 2014, the ICSID Tribunal issued its final award finding in favor of the ExxonMobil affiliates and awarding $1.6 billion as of the date of expropriation, June 27, 2007, and interest from that date at 3.25% compounded annually until the date of payment in full. The Tribunal also noted that one of the Cerro Negro Project agreements provides a mechanism to prevent double recovery between the ICSID award and all or part of an earlier award of $908 million to an ExxonMobil affiliate, Mobil Cerro Negro, Ltd., against PdVSA and a PdVSA affiliate, PdVSA CN, in an arbitration under the rules of the International Chamber of Commerce (ICC). Following the favorable ICSID decision in the fourth quarter of 2014, ExxonMobil recognized earnings of $269 million, net of the remaining asset value, for the proceeds received from the earlier ICC award.

Judgment was entered on the ICSID award by the United States District Court for the Southern District of New York on October 10, 2014. A motion to vacate that judgment on procedural grounds was filed by the Republic of Venezuela on October 14, 2014, which was denied by the court. Thereafter, the Republic of Venezuela filed a motion to modify the judgment by reducing the rate of interest to be paid on the ICSID award from the entry of the court’s judgment, until the date of payment.

On October 23, 2014, the Republic of Venezuela filed with ICSID an application to revise the ICSID award such that it requires repayment of the value of the ICC award to PdVSA at the same time as payment is made to the ExxonMobil affiliates for the ICSID award and that provision be made for interest on the amount to be repaid. Thereafter, pursuant to ICSID arbitration rules, the ICSID award was stayed pending further action of the Tribunal. On October 27, 2014, ExxonMobil filed a response with ICSID that contests the application for revision of that award on both factual and jurisdictional grounds. On February 2, 2015, the Republic of Venezuela filed an application to annul the ICSID award. The application alleges that, in issuing the ICSID award, the Tribunal exceeded its powers, failed to state reasons on which the ICSID award was based, and departed from a fundamental rule of procedure. Upon registration of the application with ICSID on February 9, 2015, a further stay of the ICSID award was entered.

The federal court in New York has stayed its judgment until such time as the stays of the ICSID award entered following the Government of Venezuela’s filing of its two applications have been lifted. The net impact of these matters on the Corporation’s consolidated financial results cannot be reasonably estimated. Regardless, the Corporation does not expect the resolution to have a material effect upon the Corporation’s operations or financial condition.

An affiliate of ExxonMobil is one of the Contractors under a Production Sharing Contract (PSC) with the Nigerian National Petroleum Corporation (NNPC) covering the Erha block located in the offshore waters of Nigeria. ExxonMobil's affiliate is the operator of the block and owns a 56.25 percent interest under the PSC. The Contractors are in dispute with NNPC regarding NNPC's lifting of crude oil in excess of its entitlement under the terms of the PSC. In accordance with the terms of the PSC, the Contractors initiated arbitration in Abuja, Nigeria, under the Nigerian Arbitration and Conciliation Act. On October 24, 2011, a three-member arbitral Tribunal issued an award upholding the Contractors' position in all material respects and awarding damages to the Contractors jointly in an amount of approximately $1.8 billion plus $234 million in accrued interest. The Contractors petitioned a Nigerian federal court for enforcement of the award, and NNPC petitioned the same court to have the award set aside. On May 22, 2012, the court set aside the award. The Contractors have appealed that judgment. In June 2013, the Contractors filed a lawsuit against NNPC in the Nigerian federal high court in order to preserve their ability to seek enforcement of the PSC in the courts if necessary. In October 2014, the Contractors filed suit in the United States District Court for the Southern District of New York to enforce, if necessary, the arbitration award against NNPC assets residing within that jurisdiction. At this time, the net impact of this matter on the Corporation's consolidated financial results cannot be reasonably estimated. However, regardless of the outcome of enforcement proceedings, the Corporation does not expect the proceedings to have a material effect upon the Corporation's operations or financial condition.

Pension And Other Postretirement Benefits

12 Months Ended

Dec. 31, 2014

Pension And Other Postretirement Benefits [Abstract]

Pension And Other Postretirement Benefits

17. 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
		U.S.		Non-U.S.		Benefits
		2014	2013	2014	2013	2014	2013
		(percent)
Weighted-average assumptions used to determine
	benefit obligations at December 31
	Discount rate	4.00	5.00	3.10	4.30	4.00	5.00
	Long-term rate of compensation increase	5.75	5.75	5.30	5.40	5.75	5.75

		(millions of dollars)
Change in benefit obligation
	Benefit obligation at January 1	17,304	19,779	27,357	28,670	7,868	9,058
	Service cost	677	801	590	697	140	176
	Interest cost	807	749	1,138	1,076	383	352
	Actuarial loss/(gain)	3,192	(1,520)	4,929	(1,454)	1,522	(1,267)
	Benefits paid (1) (2)	(1,427)	(2,520)	(1,366)	(1,311)	(525)	(511)
	Foreign exchange rate changes	-	-	(2,540)	(284)	(48)	(43)
	Amendments, divestments and other	(24)	15	(61)	(37)	96	103
Benefit obligation at December 31		20,529	17,304	30,047	27,357	9,436	7,868
Accumulated benefit obligation at December 31		16,385	13,989	26,318	23,949	-	-

(1) Benefit payments for funded and unfunded plans.

(2) For 2014 and 2013, other postretirement benefits paid are net of $21 million and $20 million of Medicare subsidy receipts, respectively.

For selection of the discount rate for U.S. plans, several sources of information are considered, including interest rate market indicators and the discount rate determined by use of a yield curve based on 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 a health care cost trend rate of 4.5 percent in 2016 and subsequent years. A one-percentage-point increase in the health care cost trend rate would increase service and interest cost by $91 million and the postretirement benefit obligation by $1,070 million. A one-percentage-point decrease in the health care cost trend rate would decrease service and interest cost by $69 million and the postretirement benefit obligation by $844 million.

		Pension Benefits				Other Postretirement
		U.S.		Non-U.S.		Benefits
		2014	2013	2014	2013	2014	2013
		(millions of dollars)
Change in plan assets
	Fair value at January 1	11,190	12,632	19,283	18,090	620	581
	Actual return on plan assets	1,497	617	3,153	1,604	41	64
	Foreign exchange rate changes	-	-	(1,738)	(270)	-	-
	Company contribution	1,476	101	554	919	31	35
	Benefits paid (1)	(1,248)	(2,171)	(912)	(869)	(224)	(60)
	Other	-	11	(245)	(191)	-	-
Fair value at December 31		12,915	11,190	20,095	19,283	468	620

(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.
		2014	2013	2014	2013
		(millions of dollars)
Assets in excess of/(less than) benefit obligation
	Balance at December 31
	Funded plans	(4,590)	(3,547)	(2,113)	(941)
	Unfunded plans	(3,024)	(2,567)	(7,839)	(7,133)
Total		(7,614)	(6,114)	(9,952)	(8,074)

The authoritative guidance for defined benefit pension and other postretirement 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
		U.S.		Non-U.S.		Benefits
		2014	2013	2014	2013	2014	2013
		(millions of dollars)
Assets in excess of/(less than) benefit obligation
	Balance at December 31 (1)	(7,614)	(6,114)	(9,952)	(8,074)	(8,968)	(7,248)

Amounts recorded in the consolidated balance
	sheet consist of:
	Other assets	-	1	302	201	-	-
	Current liabilities	(340)	(275)	(325)	(358)	(369)	(359)
	Postretirement benefits reserves	(7,274)	(5,840)	(9,929)	(7,917)	(8,599)	(6,889)
Total recorded		(7,614)	(6,114)	(9,952)	(8,074)	(8,968)	(7,248)

Amounts recorded in accumulated other
	comprehensive income consist of:
	Net actuarial loss/(gain)	6,589	4,780	9,642	7,943	2,997	1,603
	Prior service cost	27	60	429	665	51	65
Total recorded in accumulated other
	comprehensive income	6,616	4,840	10,071	8,608	3,048	1,668

(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 percentages and the long-term return assumption for each asset class.

										Other
				Pension Benefits						Postretirement
				U.S.			Non-U.S.			Benefits
				2014	2013	2012	2014	2013	2012	2014	2013	2012
Weighted-average assumptions used to
	determine net periodic benefit cost for
	years ended December 31		(percent)
	Discount rate			5.00	4.00	5.00	4.30	3.80	4.00	5.00	4.00	5.00
	Long-term rate of return on funded assets			7.25	7.25	7.25	6.30	6.40	6.60	7.25	7.25	7.25
	Long-term rate of compensation increase			5.75	5.75	5.75	5.40	5.50	5.40	5.75	5.75	5.75

Components of net periodic benefit cost				(millions of dollars)
	Service cost			677	801	665	590	697	648	140	176	134
	Interest cost			807	749	820	1,138	1,076	1,145	383	352	380
	Expected return on plan assets			(799)	(835)	(789)	(1,193)	(1,128)	(1,109)	(37)	(41)	(38)
	Amortization of actuarial loss/(gain)			409	646	576	628	852	844	116	228	170
	Amortization of prior service cost			8	7	7	120	117	117	14	21	34
	Net pension enhancement and
	curtailment/settlement cost (1)			276	723	333	-	22	1,540	-	-	-
Net periodic benefit cost				1,378	2,091	1,612	1,283	1,636	3,185	616	736	680

	(1)	Non-U.S. net pension enhancement and curtailment/settlement cost for 2012 includes $1,420 million (on a consolidated-company, before-tax basis) of accumulated other comprehensive income for the postretirement benefit reserves adjustment that was recycled into earnings and included in the Japan restructuring gain reported in “Other income”.




Changes in amounts recorded in accumulated
	other comprehensive income:
	Net actuarial loss/(gain)			2,494	(1,302)	1,885	2,969	(1,938)	1,906	1,518	(1,290)	1,008
	Amortization of actuarial (loss)/gain			(685)	(1,369)	(909)	(628)	(874)	(2,384)	(116)	(228)	(170)
	Prior service cost/(credit)			(25)	-	-	(70)	30	71	-	-	-
	Amortization of prior service (cost)/credit			(8)	(7)	(7)	(120)	(117)	(117)	(14)	(21)	(34)
	Foreign exchange rate changes			-	-	-	(688)	(155)	271	(8)	(10)	3
Total recorded in other comprehensive income				1,776	(2,678)	969	1,463	(3,054)	(253)	1,380	(1,549)	807
Total recorded in net periodic benefit cost and
	other comprehensive income, before tax			3,154	(587)	2,581	2,746	(1,418)	2,932	1,996	(813)	1,487

Costs for defined contribution plans were $393 million, $392 million and $382 million in 2014, 2013 and 2012, respectively.

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

		Total Pension and
		Other Postretirement Benefits
		2014	2013	2012
		(millions of dollars)
(Charge)/credit to other comprehensive income, before tax
	U.S. pension	(1,776)	2,678	(969)
	Non-U.S. pension	(1,463)	3,054	253
	Other postretirement benefits	(1,380)	1,549	(807)
Total (charge)/credit to other comprehensive income, before tax		(4,619)	7,281	(1,523)
(Charge)/credit to income tax (see Note 4)		1,549	(2,336)	393
(Charge)/credit to investment in equity companies		(81)	49	(49)
(Charge)/credit to other comprehensive income including noncontrolling
	interests, after tax	(3,151)	4,994	(1,179)
Charge/(credit) to equity of noncontrolling interests		85	(279)	(124)
(Charge)/credit to other comprehensive income attributable to ExxonMobil		(3,066)	4,715	(1,303)

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 percentages. The target asset allocation for the U.S. benefit plans and for the non-U.S. plans in aggregate is 40 percent equity securities and 60 percent debt securities. 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 percent and 3 percent, 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 2014 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									Fair Value Measurement
			at December 31, 2014, Using:									at December 31, 2014, Using:
				Quoted									Quoted
				Prices									Prices
				in Active	Significant								in Active		Significant
			Markets for			Other		Significant				Markets for				Other		Significant
				Identical	Observable			Unobservable					Identical		Observable			Unobservable
				Assets		Inputs			Inputs				Assets			Inputs			Inputs
				(Level 1)		(Level 2)			(Level 3)		Total		(Level 1)			(Level 2)			(Level 3)		Total
				(millions of dollars)
Asset category:
	Equity securities
		U.S.		-		2,331	(1)		-		2,331		-			3,284	(1)		-		3,284
		Non-U.S.		-		2,144	(1)		-		2,144		229	(2)		3,776	(1)		-		4,005
	Private equity			-		-			562	(3)	562		-			-			535	(3)	535
	Debt securities
		Corporate		-		4,841	(4)		-		4,841		-			2,686	(4)		-		2,686
		Government		-		2,890	(4)		-		2,890		249	(5)		9,050	(4)		-		9,299
		Asset-backed		-		5	(4)		-		5		-			146	(4)		-		146
	Real estate funds			-		-			-		-		-			-			57	(6)	57
	Cash			-		131	(7)		-		131		25			31	(8)		-		56
Total at fair value				-		12,342			562		12,904		503			18,973			592		20,068
	Insurance contracts
		at contract value									11										27
Total plan assets											12,915										20,095

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

(7) For cash balances held in the form of short-term fund units that are redeemable at the measurement date, the fair value is treated as a Level 2 input.

(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, 2014, Using:
				Quoted
				Prices
				in Active	Significant
				Markets for	Other		Significant
				Identical	Observable		Unobservable
				Assets	Inputs		Inputs
				(Level 1)	(Level 2)		(Level 3)		Total
				(millions of dollars)
Asset category:
	Equity securities
		U.S.		-	106	(1)	-		106
		Non-U.S.		-	75	(1)	-		75
	Private equity			-	-		2	(2)	2
	Debt securities
		Corporate		-	103	(3)	-		103
		Government		-	171	(3)	-		171
		Asset-backed		-	9	(3)	-		9
	Cash			-	2		-		2
Total at fair value				-	466		2		468

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.
For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings.
For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions.

The change in the fair value in 2014 of Level 3 assets that use significant unobservable inputs to measure fair value is shown in the table below:

	2014
	Pension			Other
	U.S.	Non-U.S.		Postretirement

	Private	Private	Real	Private
	Equity	Equity	Estate	Equity
	(millions of dollars)

Fair value at January 1	523	502	136	9
Net realized gains/(losses)	2	23	(17)	-
Net unrealized gains/(losses)	89	31	8	-
Net purchases/(sales)	(52)	(21)	(70)	(7)
Fair value at December 31	562	535	57	2

The 2013 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									Fair Value Measurement
			at December 31, 2013, Using:									at December 31, 2013, Using:
				Quoted									Quoted
				Prices									Prices
				in Active	Significant								in Active		Significant
			Markets for			Other		Significant				Markets for				Other		Significant
				Identical	Observable			Unobservable					Identical		Observable			Unobservable
				Assets		Inputs			Inputs				Assets			Inputs			Inputs
				(Level 1)		(Level 2)			(Level 3)		Total		(Level 1)			(Level 2)			(Level 3)		Total
			(millions of dollars)
Asset category:
	Equity securities
		U.S.		-		2,514	(1)		-		2,514		-			3,046	(1)		-		3,046
		Non-U.S.		-		2,622	(1)		-		2,622		294	(2)		5,608	(1)		-		5,902
	Private equity			-		-			523	(3)	523		-			-			502	(3)	502
	Debt securities
		Corporate		-		3,430	(4)		-		3,430		-			2,125	(4)		-		2,125
		Government		-		2,056	(4)		-		2,056		272	(5)		7,100	(4)		-		7,372
		Asset-backed		-		6	(4)		-		6		-			103	(4)		-		103
	Real estate funds			-		-			-		-		-			-			136	(6)	136
	Cash			-		27	(7)		-		27		57			20	(8)		-		77
Total at fair value				-		10,655			523		11,178		623			18,002			638		19,263
	Insurance contracts
		at contract value									12										20
Total plan assets											11,190										19,283

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

(7) For cash balances held in the form of short-term fund units that are redeemable at the measurement date, the fair value is treated as a Level 2 input.

(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, 2013, Using:
				Quoted
				Prices
				in Active	Significant
				Markets for	Other		Significant
				Identical	Observable		Unobservable
				Assets	Inputs		Inputs
				(Level 1)	(Level 2)		(Level 3)		Total
			(millions of dollars)
Asset category:
	Equity securities
		U.S.		-	157	(1)	-		157
		Non-U.S.		-	149	(1)	-		149
	Private equity			-	-		9	(2)	9
	Debt securities
		Corporate		-	129	(3)	-		129
		Government		-	168	(3)	-		168
		Asset-backed		-	4	(3)	-		4
	Cash			-	4		-		4
Total at fair value				-	611		9		620

(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.

The change in the fair value in 2013 of Level 3 assets that use significant unobservable inputs to measure fair value is shown in the table below:

	2013
	Pension			Other
	U.S.	Non-U.S.		Postretirement
	Private	Private	Real	Private
	Equity	Equity	Estate	Equity
	(millions of dollars)

Fair value at January 1	489	448	293	7
Net realized gains/(losses)	(1)	11	(13)	-
Net unrealized gains/(losses)	86	57	10	3
Net purchases/(sales)	(51)	(14)	(154)	(1)
Fair value at December 31	523	502	136	9

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.
			2014	2013		2014	2013
		(millions of dollars)
For funded pension plans with an accumulated benefit obligation
	in excess of plan assets:
	Projected benefit obligation		17,505	14,737		5,031	891
	Accumulated benefit obligation		14,493	12,342		4,590	689
	Fair value of plan assets		12,915	11,189		3,890	611

For unfunded pension plans:
	Projected benefit obligation		3,024	2,567		7,839	7,133
	Accumulated benefit obligation		1,892	1,647		6,573	6,070

					Other
		Pension Benefits			Postretirement
		U.S.		Non-U.S.	Benefits
		(millions of dollars)
Estimated 2015 amortization from accumulated other comprehensive income:
	Net actuarial loss/(gain) (1)		1,001	753		211
	Prior service cost (2)		6	105		14

(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
					Medicare
		U.S.	Non-U.S.	Gross	Subsidy Receipt
		(millions of dollars)

Contributions expected in 2015		-	560	-		-
Benefit payments expected in:
	2015	1,628	1,194	467		24
	2016	1,554	1,213	479		25
	2017	1,529	1,278	490		26
	2018	1,445	1,298	499		28
	2019	1,410	1,339	507		29
	2020 - 2024	6,714	6,988	2,613		172

Disclosures About Segments And Related Information

12 Months Ended

Dec. 31, 2014

Disclosures About Segments And Related Information [Abstract]

Disclosures About Segments And Related Information

18. 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 to assess its performance; and (3) for which discrete financial information is available.

Earnings after income tax include transfers at estimated market prices.

In corporate and financing activities, interest revenue relates to interest earned on cash deposits and marketable securities. Interest expense includes non-debt-related interest expense of $129 million and $202 million in 2014 and 2012, respectively. For 2013, non-debt-related interest expense was a net credit of $123 million, primarily reflecting the effect of credits from the favorable resolution of prior year tax positions.

													Corporate
	Upstream				Downstream				Chemical					and	Corporate
	U.S.		Non-U.S.		U.S.		Non-U.S.		U.S.		Non-U.S.		Financing			Total
		(millions of dollars)
As of December 31, 2014
Earnings after income tax		5,197		22,351		1,618		1,427		2,804		1,511		(2,388)		32,520
Earnings of equity companies included above		1,235		10,859		29		82		186		1,377		(445)		13,323
Sales and other operating revenue (1)		14,826		22,336		118,771		199,976		15,115		23,063		18		394,105
Intersegment revenue		7,723		38,846		17,281		44,231		10,117		8,098		274		-
Depreciation and depletion expense		5,139		8,523		654		1,228		370		645		738		17,297
Interest revenue		-		-		-		-		-		-		75		75
Interest expense		40		17		6		4		-		-		219		286
Income taxes		1,300		15,165		610		968		1,032		358		(1,418)		18,015
Additions to property, plant and equipment		9,098		19,225		1,050		1,356		1,564		564		1,399		34,256
Investments in equity companies		5,089		10,877		69		1,006		258		3,026		(308)		20,017
Total assets		92,555		161,033		18,371		33,299		8,798		18,449		16,988		349,493

As of December 31, 2013
Earnings after income tax		4,191		22,650		2,199		1,250		2,755		1,073		(1,538)		32,580
Earnings of equity companies included above		1,576		11,627		(460)		22		189		1,422		(449)		13,927
Sales and other operating revenue (1)		13,712		25,349		123,802		218,904		15,295		23,753		21		420,836
Intersegment revenue		8,343		45,761		20,781		52,624		11,993		8,232		285		-
Depreciation and depletion expense		5,170		8,277		633		1,390		378		632		702		17,182
Interest revenue		-		-		-		-		-		-		87		87
Interest expense		30		26		7		8		1		-		(63)		9
Income taxes		2,197		21,554		721		481		989		363		(2,042)		24,263
Additions to property, plant and equipment		7,480		26,075		616		1,072		840		272		1,386		37,741
Investments in equity companies		4,975		9,740		62		1,749		217		3,103		(227)		19,619
Total assets		88,698		157,465		19,261		40,661		7,816		19,659		13,248		346,808

As of December 31, 2012
Earnings after income tax		3,925		25,970		3,575		9,615		2,220		1,678		(2,103)		44,880
Earnings of equity companies included above		1,759		11,900		6		387		183		1,267		(492)		15,010
Sales and other operating revenue (1)		11,039		27,673		125,088		248,959		14,723		24,003		24		451,509
Intersegment revenue		8,764		47,507		20,963		62,130		12,409		9,750		258		-
Depreciation and depletion expense		5,104		7,340		594		1,280		376		508		686		15,888
Interest revenue		-		-		-		-		-		-		117		117
Interest expense		37		13		3		36		-		(1)		239		327
Income taxes		2,025		25,362		1,811		1,892		755		232		(1,032)		31,045
Additions to property, plant and equipment		9,697		21,769		480		1,153		338		659		1,083		35,179
Investments in equity companies		4,020		9,147		195		2,069		233		3,143		(277)		18,530
Total assets		86,146		140,848		18,451		40,956		7,238		18,886		21,270		333,795

(1) Sales and other operating revenue includes sales-based taxes of $29,342 million for 2014, $30,589 million for 2013 and $32,409 million for 2012. See Note 1, Summary of Accounting Policies.

Geographic

Sales and other operating revenue (1)		2014	2013	2012
		(millions of dollars)

United States		148,713	152,820	150,865
Non-U.S.		245,392	268,016	300,644
	Total	394,105	420,836	451,509

Significant non-U.S. revenue sources include:
	Canada	36,072	35,924	34,325
	United Kingdom	31,346	34,061	33,600
	Belgium	20,953	20,973	23,567
	Italy	18,880	19,273	18,228
	France	17,639	18,444	19,601
	Singapore	15,407	15,623	14,606
	Germany	14,816	15,701	15,871

(1) Sales and other operating revenue includes sales-based taxes of $29,342 million for 2014, $30,589 million for 2013 and $32,409 million for 2012. See Note 1, Summary of Accounting Policies.

Long-lived assets		2014	2013	2012
		(millions of dollars)

United States		104,000	98,271	94,336
Non-U.S.		148,668	145,379	132,613
	Total	252,668	243,650	226,949

Significant non-U.S. long-lived assets include:
	Canada	43,858	41,522	31,979
	Australia	15,328	14,258	13,415
	Nigeria	12,265	12,343	12,216
	Singapore	9,620	9,570	9,700
	Kazakhstan	9,138	8,530	7,785
	Angola	9,057	8,262	8,238
	Papua New Guinea	6,099	5,768	4,599
	Norway	5,139	6,542	7,040

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
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Income, Sales-Based And Other Taxes [Abstract]

Income, Sales-Based And Other Taxes

12 Months Ended

Dec. 31, 2014

Income, Sales-Based And Other Taxes

19. Income, Sales-Based and Other Taxes

						2014				2013				2012
				U.S.	Non-U.S.		Total	U.S.	Non-U.S.		Total	U.S.	Non-U.S.		Total
								(millions of dollars)
Income tax expense
	Federal and non-U.S.
		Current		1,456		14,755	16,211	1,073		22,115	23,188	1,791		25,650	27,441
		Deferred - net		900		1,398	2,298	(116)		757	641	1,097		1,816	2,913
	U.S. tax on non-U.S. operations			5		-	5	37		-	37	89		-	89
			Total federal and non-U.S.	2,361		16,153	18,514	994		22,872	23,866	2,977		27,466	30,443
	State (1)			(499)		-	(499)	397		-	397	602		-	602
			Total income tax expense	1,862		16,153	18,015	1,391		22,872	24,263	3,579		27,466	31,045
Sales-based taxes				6,310		23,032	29,342	5,992		24,597	30,589	5,785		26,624	32,409
All other taxes and duties
	Other taxes and duties			378		31,908	32,286	955		32,275	33,230	1,406		34,152	35,558
	Included in production and
		manufacturing expenses		1,454		1,179	2,633	1,318		1,182	2,500	1,242		1,308	2,550
	Included in SG&A expenses			155		441	596	150		516	666	154		595	749
		Total other taxes and duties		1,987		33,528	35,515	2,423		33,973	36,396	2,802		36,055	38,857
			Total	10,159		72,713	82,872	9,806		81,442	91,248	12,166		90,145	102,311

(1) In 2014, state taxes included a favorable adjustment of deferred taxes of approximately $830 million.

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 net credits of $40 million in 2014 and $310 million in 2013 and a net charge of $244 million in 2012 for the effect of changes in tax laws and rates.

The reconciliation between income tax expense and a theoretical U.S. tax computed by applying a rate of 35 percent for 2014, 2013 and 2012 is as follows:

			2014	2013	2012
			(millions of dollars)
Income before income taxes
	United States		9,080	9,746	11,222
	Non-U.S.		42,550	47,965	67,504
		Total	51,630	57,711	78,726
Theoretical tax			18,071	20,199	27,554
Effect of equity method of accounting			(4,663)	(4,874)	(5,254)
Non-U.S. taxes in excess of theoretical U.S. tax			5,442	10,528	8,434
U.S. tax on non-U.S. operations			5	37	89
State taxes, net of federal tax benefit			(324)	258	391
Other			(516)	(1,885)	(169)
		Total income tax expense	18,015	24,263	31,045

Effective tax rate calculation
Income taxes			18,015	24,263	31,045
ExxonMobil share of equity company income taxes			5,678	6,061	5,859
		Total income taxes	23,693	30,324	36,904
Net income including noncontrolling interests			33,615	33,448	47,681
		Total income before taxes	57,308	63,772	84,585

Effective income tax rate			41%	48%	44%

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:		2014	2013
		(millions of dollars)

Property, plant and equipment		51,643	50,884
Other liabilities		4,359	3,474
	Total deferred tax liabilities	56,002	54,358

Pension and other postretirement benefits		(8,140)	(6,573)
Asset retirement obligations		(6,162)	(6,083)
Tax loss carryforwards		(4,099)	(3,393)
Other assets		(6,446)	(6,246)
	Total deferred tax assets	(24,847)	(22,295)

Asset valuation allowances		2,570	2,491
	Net deferred tax liabilities	33,725	34,554

In 2014, asset valuation allowances of $2,570 million increased by $79 million and included additional net provisions of $340 million and effects of foreign currency translation of $(261) million.

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		2014	2013
		(millions of dollars)

Other current assets		(2,001)	(3,575)
Other assets, including intangibles, net		(3,955)	(2,822)
Accounts payable and accrued liabilities		451	421
Deferred income tax liabilities		39,230	40,530
	Net deferred tax liabilities	33,725	34,554

The Corporation had $51 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. The following table summarizes the movement in unrecognized tax benefits:

Gross unrecognized tax benefits		2014	2013	2012
		(millions of dollars)

Balance at January 1		7,838	7,663	4,922
	Additions based on current year's tax positions	1,454	1,460	1,662
	Additions for prior years' tax positions	448	464	2,559
	Reductions for prior years' tax positions	(532)	(249)	(535)
	Reductions due to lapse of the statute of limitations	(117)	(588)	(79)
	Settlements with tax authorities	(43)	(849)	(855)
	Foreign exchange effects/other	(62)	(63)	(11)
Balance at December 31		8,986	7,838	7,663

The gross unrecognized tax benefit balances shown above are predominantly related to tax positions that would reduce the Corporation’s effective tax rate if the positions are favorably resolved. Unfavorable resolution of these tax positions generally would not increase the effective tax rate. The 2014, 2013 and 2012 changes in unrecognized tax benefits did not have a material effect on the Corporation’s net income.

Resolution of these 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 30 percent in the next 12 months, with no material impact on the Corporation’s net income.

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

	Country of Operation	Open Tax Years
	Abu Dhabi	2012 - 2014
	Angola	2009 - 2014
	Australia:	2000 - 2003
		2005
		2008 - 2014
	Canada	2007 - 2014
	Equatorial Guinea	2007 - 2014
	Malaysia	2008 - 2014
	Nigeria	2004 - 2014
	Norway	2005 - 2014
	Qatar	2008 - 2014
	Russia	2011 - 2014
	United Kingdom	2010 - 2014
	United States	2006 - 2014

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

The Corporation incurred $42 million in interest expense on income tax reserves in 2014. For 2013, the Corporation’s net interest expense was a credit of $207 million, reflecting the effect of credits from the favorable resolution of prior year tax positions. The Corporation incurred $46 million in interest expense in 2012. The related interest payable balances were $205 million and $156 million at December 31, 2014, and 2013, respectively.

Summary Of Accounting Policies (Policy)	12 Months Ended
Summary Of Accounting Policies (Policy)	Dec. 31, 2014
Summary Of Accounting Policies [Abstract]
Principles Of Consolidation	Principles of Consolidation. The Consolidated Financial Statements include the accounts of subsidiaries the Corporation controls. They also include the Corporation’s share of the undivided interest in certain upstream assets, liabilities, revenues and expenses. Amounts representing the Corporation’s interest in entities that it does not control, but over which it exercises significant influence, 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.” Majority ownership is normally the indicator of control that is the basis on which subsidiaries are consolidated. However, certain factors may indicate that a majority-owned investment is not controlled and therefore should be accounted for using the equity method of accounting. These factors occur where the minority shareholders are granted by law or by contract substantive participating rights. These include the right to approve operating policies, expense budgets, financing and investment plans, and management compensation and succession plans. The Corporation’s share of the cumulative foreign exchange translation adjustment for equity method investments is reported in Accumulated Other Comprehensive Income. 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, 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. 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).
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. The gains and losses resulting from changes in the fair value of derivatives are recorded in income. In some cases, the Corporation designates derivatives as fair value hedges, in which case the gains and losses are offset in income by the gains and losses arising from changes in the fair value of the underlying hedged item.
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 and 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. 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. Costs incurred to purchase, lease, or otherwise acquire a property (whether unproved or proved) are capitalized when incurred. Exploratory well costs are carried as an asset 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. Other exploratory expenditures, including geophysical costs and annual lease rentals, are expensed as incurred. Development costs including costs of productive wells and development dry holes are capitalized. Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves. Capitalized exploratory drilling and development costs associated with productive depletable extractive properties are amortized using unit-of-production rates 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 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 and are expensed as incurred. 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. 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 and natural gas commodity prices, refining and chemical margins and foreign currency exchange rates. Annual volumes are based on field production profiles, which are also updated annually. Prices for other petroleum and chemical 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. An asset group would be impaired if the undiscounted cash flows were less than its carrying value. Impairments are measured by the amount the carrying value exceeds fair value. 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. Gains on sales of proved and unproved properties are only recognized when there is neither uncertainty about the recovery of costs applicable to any interest retained nor any 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. 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.
Asset Retirement Obligations And Environmental Liabilities	Asset Retirement Obligations and Environmental Liabilities. The Corporation incurs retirement obligations for certain 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 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 price of the stock at the date of grant and is recognized in income over the requisite service period.

Miscellaneous Financial Information (Tables)

12 Months Ended

Dec. 31, 2014

Miscellaneous Financial Information [Abstract]

Crude Oil, Products And Merchandise

		2014	2013
		(billions of dollars)

Petroleum products		4.1	3.9
Crude oil		4.6	4.7
Chemical products		2.9	2.9
Gas/other		0.8	0.6
	Total	12.4	12.1

Other Comprehensive Income Information (Tables)

12 Months Ended

Dec. 31, 2014

Other Comprehensive Income Information [Abstract]

Schedule Of Accumulated Other Comprehensive Income Information

		Cumulative	Post-
		Foreign	retirement	Unrealized
		Exchange	Benefits	Change in
ExxonMobil Share of Accumulated Other		Translation	Reserves	Stock
Comprehensive Income		Adjustment	Adjustment	Investments	Total
		(millions of dollars)
Balance as of December 31, 2011		4,168	(13,291)	-	(9,123)
Current period change excluding amounts reclassified
	from accumulated other comprehensive income	842	(3,402)	-	(2,560)
Amounts reclassified from accumulated other
	comprehensive income	(2,600)	2,099	-	(501)
Total change in accumulated other comprehensive income		(1,758)	(1,303)	-	(3,061)
Balance as of December 31, 2012		2,410	(14,594)	-	(12,184)

Balance as of December 31, 2012		2,410	(14,594)	-	(12,184)
Current period change excluding amounts reclassified
	from accumulated other comprehensive income	(3,233)	2,963	-	(270)
Amounts reclassified from accumulated other
	comprehensive income	(23)	1,752	-	1,729
Total change in accumulated other comprehensive income		(3,256)	4,715	-	1,459
Balance as of December 31, 2013		(846)	(9,879)	-	(10,725)

Balance as of December 31, 2013		(846)	(9,879)	-	(10,725)
Current period change excluding amounts reclassified
	from accumulated other comprehensive income	(5,258)	(4,132)	(63)	(9,453)
Amounts reclassified from accumulated other
	comprehensive income	152	1,066	3	1,221
Total change in accumulated other comprehensive income		(5,106)	(3,066)	(60)	(8,232)
Balance as of December 31, 2014		(5,952)	(12,945)	(60)	(18,957)

Reclassification Out Of Accumulated Other Comprehensive Income

Amounts Reclassified Out of Accumulated Other
Comprehensive Income - Before-tax Income/(Expense)		2014	2013	2012
		(millions of dollars)
Foreign exchange translation gain/(loss) included in net income
	(Statement of Income line: Other income)	(152)	23	4,352
Amortization and settlement of postretirement benefits reserves
	adjustment included in net periodic benefit costs (1)	(1,571)	(2,616)	(3,621)
Realized change in fair value of stock investments included in net income
	(Statement of Income line: Other income)	(5)	-	-

Schedule Of Income Tax (Expense)/Credit For Components Of Other Comprehensive Income

Income Tax (Expense)/Credit For
Components of Other Comprehensive Income		2014	2013	2012
		(millions of dollars)
Foreign exchange translation adjustment		292	218	(236)
Postretirement benefits reserves adjustment (excluding amortization)		2,009	(1,540)	1,619
Amortization and settlement of postretirement benefits reserves
	adjustment included in net periodic benefit costs	(460)	(796)	(1,226)
Unrealized change in fair value of stock investments		34	-	-
Realized change in fair value of stock investments included in net income		(2)	-	-
Total		1,873	(2,118)	157

Cash Flow Information (Tables)

12 Months Ended

Dec. 31, 2014

Cash Flow Information [Abstract]

Cash payments for interest and income taxes

Additional Working Capital Information (Tables)

12 Months Ended

Dec. 31, 2014

Additional Working Capital Information [Abstract]

Schedule Of Notes, Accounts Receivable And Payable, Loans Payable, And Accrued Liabilities

			Dec. 31	Dec. 31
			2014	2013
			(millions of dollars)
Notes and accounts receivable
	Trade, less reserves of $113 million and $112 million		18,541	25,993
	Other, less reserves of $48 million and $28 million		9,468	7,159
		Total	28,009	33,152

Notes and loans payable
	Bank loans		473	723
	Commercial paper		16,225	14,051
	Long-term debt due within one year		770	1,034
		Total	17,468	15,808

Accounts payable and accrued liabilities
	Trade payables		25,286	30,920
	Payables to equity companies		6,589	6,587
	Accrued taxes other than income taxes		3,290	3,883
	Other		7,062	6,695
		Total	42,227	48,085

Equity Company Information (Tables)

12 Months Ended

Dec. 31, 2014

Equity Company Information [Abstract]

Schedule Of Equity Company Financial Summary

		2014			2013			2012
Equity Company			ExxonMobil			ExxonMobil			ExxonMobil
Financial Summary		Total		Share	Total		Share	Total		Share
		(millions of dollars)

Total revenues		183,708		55,855	236,161		68,084	224,953		67,572
Income before income taxes		65,549		19,014	69,454		19,999	69,411		20,882
Income taxes		20,520		5,684	21,618		6,069	20,703		5,868
	Income from equity affiliates	45,029		13,330	47,836		13,930	48,708		15,014

Current assets		49,905		16,802	62,398		19,545	59,612		18,483
Long-term assets		110,754		33,619	116,450		35,695	111,131		33,798
	Total assets	160,659		50,421	178,848		55,240	170,743		52,281
Current liabilities		37,333		11,472	54,550		15,243	49,698		14,265
Long-term liabilities		66,231		19,470	68,857		20,873	68,855		19,715
	Net assets	57,095		19,479	55,441		19,124	52,190		18,301

Schedule Of The Corporation's Percentage Ownership Interest

		Percentage
		Ownership
		Interest
	Upstream
	Aera Energy LLC	48
	BEB Erdgas und Erdoel GmbH & Co. KG	50
	Cameroon Oil Transportation Company S.A.	41
	Cross Timbers Energy, LLC	50
	Golden Pass LNG Terminal LLC	18
	Karmorneftegaz Holding SARL	33
	Marine Well Containment Company LLC	10
	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.	71

	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
	Infineum USA L.P.	50
	Saudi Yanbu Petrochemical Co.	50

Investments, Advances And Long-Term Receivables (Tables)

12 Months Ended

Dec. 31, 2014

Investments, Advances And Long-Term Receivables [Abstract]

Schedule Of Investments, Advances And Long-Term Receivables

			Dec. 31,	Dec. 31,
			2014	2013
			(millions of dollars)
Companies carried at equity in underlying assets
	Investments		20,017	19,619
	Advances		9,818	10,476
		Total equity company investments and advances	29,835	30,095
Companies carried at cost or less and stock investments carried at fair value			526	115
Long-term receivables and miscellaneous investments at cost or less, net of reserves
	of $2,662 million and $2,938 million		4,878	6,118
		Total	35,239	36,328

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

12 Months Ended

Dec. 31, 2014

Property, Plant And Equipment And Asset Retirement Obligations [Abstract]

Property, Plant And Equipment

		December 31, 2014		December 31, 2013
Property, Plant and Equipment		Cost	Net	Cost	Net
		(millions of dollars)

Upstream		347,170	205,308	336,359	197,554
Downstream		53,327	22,639	54,456	23,219
Chemical		30,717	14,918	29,487	13,965
Other		15,575	9,803	14,215	8,912
	Total	446,789	252,668	434,517	243,650

Asset Retirement Obligations

		2014	2013
		(millions of dollars)

Beginning balance		12,988	11,973
	Accretion expense and other provisions	871	785
	Reduction due to property sales	(151)	(97)
	Payments made	(724)	(664)
	Liabilities incurred	122	603
	Foreign currency translation	(908)	(344)
	Revisions	1,226	732
Ending balance		13,424	12,988

Accounting For Suspended Exploratory Well Costs (Tables)

12 Months Ended

Dec. 31, 2014

Accounting For Suspended Exploratory Well Costs [Abstract]

Change In Capitalized Suspended Exploratory Well Costs

			2014	2013	2012
			(millions of dollars)

Balance beginning at January 1			2,707	2,679	2,881
	Additions pending the determination of proved reserves		1,095	293	868
	Charged to expense		(28)	(52)	(95)
	Reclassifications to wells, facilities and equipment based on the
		determination of proved reserves	(160)	(107)	(631)
	Divestments/Other		(27)	(106)	(344)
Ending balance at December 31			3,587	2,707	2,679
Ending balance attributed to equity companies included above			645	13	3

Period End Capitalized Suspended Exploratory Well Costs

			2014	2013	2012
			(millions of dollars)

Capitalized for a period of one year or less			1,095	293	866
	Capitalized for a period of between one and five years		1,659	1,705	1,176
	Capitalized for a period of between five and ten years		544	470	401
	Capitalized for a period of greater than ten years		289	239	236
Capitalized for a period greater than one year - subtotal			2,492	2,414	1,813
		Total	3,587	2,707	2,679

Number Of Projects With Suspended Exploratory Well Costs

			2014	2013	2012
Number of projects with first capitalized well drilled in the preceding 12 months			8	8	10
Number of projects that have exploratory well costs capitalized for a period
	of greater than 12 months		53	50	45
		Total	61	58	55

Additional Detail For The 38 Projects With Completed Exploratory Activity Progressing Toward Development

			Years
		Dec. 31,	Wells
Country/Project		2014	Drilled	Comment
	(millions of dollars)
Angola
- Kaombo Split Hub Phase 2		20	2005 - 2006	Evaluating development plan to tie into planned production facilities.
- Perpetua-Zinia-Acacia		15	2008 - 2009	Oil field near Pazflor development, awaiting capacity in existing/planned infrastructure.
Australia
- East Pilchard		8	2001	Gas field near Kipper/Tuna development, awaiting capacity in existing/planned
				infrastructure.
- SE Longtom		12	2010	Gas field near Tuna development, awaiting capacity in existing/planned infrastructure.
- SE Remora		38	2010	Gas field near Marlin development, awaiting capacity in existing/planned infrastructure.
Indonesia
- Alas Tua West		16	2010	Evaluating development plan to tie into planned production facilities.
- Cepu Gas		28	2008 - 2011	Development activity under way, while continuing commercial discussions with the
				government.
- Kedung Keris		11	2011	Evaluating development plan to tie into planned production facilities.
- Natuna		118	1981 - 1983	Development activity under way, while continuing discussions with the government
				on contract terms pursuant to executed Heads of Agreement.
Kazakhstan
- Kairan		53	2004 - 2007	Evaluating commercialization and field development alternatives, while continuing
				discussions with the government regarding the development plan.
Malaysia
- Besar		18	1992 - 2010	Gas field off the east coast of Malaysia; progressing development plan.
- Bindu		2	1995	Awaiting capacity in existing/planned infrastructure.
Nigeria
- Bolia		15	2002 - 2006	Evaluating development plan, while continuing discussions with the government
				regarding regional hub strategy.
- Bosi		79	2002 - 2006	Development activity under way, while continuing discussions with the government
				regarding development plan.
- Bosi Central		16	2006	Development activity under way, while continuing discussions with the government
				regarding development plan.
- Erha Northeast		26	2008	Evaluating development plan for tieback to existing production facilities.
- Owowo		50	2009 - 2012	Continuing discussions with the government regarding contract terms.
- Pegi		32	2009	Awaiting capacity in existing/planned infrastructure.
- Satellite Field		12	2013	Evaluating development plan to tie into planned production facilities.
Development Phase 2
- Other (4 projects)		14	2002	Evaluating and pursuing development of several additional discoveries.
Norway
- Gamma		15	2008 - 2009	Evaluating development plan for tieback to existing production facilities.
- Lavrans		18	1995 - 1999	Evaluating development plan, awaiting capacity in existing Kristin production facility.
- Other (7 projects)		29	2008 - 2013	Evaluating development plans, including potential for tieback to existing production
				facilities.
Papua New Guinea
- Juha		28	2007	Progressing development plans to tie into existing LNG facilities.
- P'nyang		58	2012	Evaluating development alternatives to tie into existing/planned infrastructure.
Republic of Congo
- Mer Tres Profonde Sud		56	2000 - 2007	Evaluating development alternatives, while continuing discussions with the government
				regarding development plan.
United Kingdom
- Phyllis		8	2004	Evaluating development plan for tieback to existing production facilities.
United States
- Hadrian North		209	2010 - 2013	Evaluating development plan to tie into existing production facilities.
- Tip Top		31	2009	Evaluating development concept and requisite facility upgrades.
Total 2014 (38 projects)		1,035

Leased Facilities (Tables)

12 Months Ended

Dec. 31, 2014

Leased Facilities [Abstract]

Leased Facilities

		Related
	Lease Payments	Sublease
	Under Minimum	Rental
	Commitments	Income
	(millions of dollars)

2015	2,034	31
2016	1,379	7
2017	774	6
2018	418	3
2019	312	3
2020 and beyond	1,296	20
Total	6,213	70

Net Rental Cost

	2014	2013	2012
	(millions of dollars)

Rental cost	4,077	3,841	3,851
Less sublease rental income	52	44	44
Net rental cost	4,025	3,797	3,807

Earnings Per Share (Tables)

12 Months Ended

Dec. 31, 2014

Earnings Per Share [Abstract]

Earnings Per Share Computation

	2014	2013	2012
Earnings per common share

Net income attributable to ExxonMobil (millions of dollars)	32,520	32,580	44,880

Weighted average number of common shares outstanding (millions of shares)	4,282	4,419	4,628

Earnings per common share (dollars) (1)	7.60	7.37	9.70

Dividends paid per common share (dollars)	2.70	2.46	2.18

(1) The earnings per common share and earnings per common share - assuming dilution are the same in each period shown.

Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2014

Long-Term Debt [Abstract]

Summarized Long-Term Debt

			2014	2013
			(millions of dollars)
Exxon Mobil Corporation
	0.921% notes due 2017		1,500	-
	Floating-rate notes due 2017 (1)		750	-
	1.819% notes due 2019		1,750	-
	Floating-rate notes due 2019 (2)		500	-
	3.176% notes due 2024		1,000	-

XTO Energy Inc. (3)
	5.000% senior notes due 2015		-	132
	5.300% senior notes due 2015		-	243
	5.650% senior notes due 2016		207	212
	6.250% senior notes due 2017		477	489
	5.500% senior notes due 2018		383	389
	6.500% senior notes due 2018		474	485
	6.100% senior notes due 2036		199	200
	6.750% senior notes due 2037		309	312
	6.375% senior notes due 2038		236	238

Mobil Producing Nigeria Unlimited (4)
	Variable notes due 2015-2019		399	742

Esso (Thailand) Public Company Ltd. (5)
	Variable notes due 2015-2019		121	177

Mobil Corporation
	8.625% debentures due 2021		249	249

Industrial revenue bonds due 2015-2051 (6)			2,611	2,527
Other U.S. dollar obligations (7)			104	112
Other foreign currency obligations			9	9
Capitalized lease obligations (8)			375	375
		Total long-term debt	11,653	6,891

(1) Average effective interest rate of 0.3% in 2014.

(2) Average effective interest rate of 0.4% in 2014.

(3) Includes premiums of $219 million in 2014 and $271 million in 2013.

(4) Average effective interest rate of 4.5% in 2014 and 4.6% in 2013.

(5) Average effective interest rate of 2.4% in 2014 and 3.3% in 2013.

(6) Average effective interest rate of 0.03% in 2014 and 0.06% in 2013.

(7) Average effective interest rate of 4.2% in 2014 and 4.4% in 2013.

(8) Average imputed interest rate of 7.0% in 2014 and 7.8% in 2013.

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21475-112644

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 470
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6479336&loc=d3e64711-112823

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(e),(f))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=34725769&loc=d3e28878-108400

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21538-112644

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21506-112644

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28541-108399

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28551-108399

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21521-112644

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph 22
-Article 5

Summary Of Restricted Stock And Units Outstanding

Incentive Program (Tables)

12 Months Ended

Dec. 31, 2014

Incentive Program [Abstract]

	2014
		Weighted Average
		Grant-Date
Restricted stock and units outstanding	Shares	Fair Value per Share
	(thousands)	(dollars)

Issued and outstanding at January 1	45,207		78.29
2013 award issued in 2014	9,705		94.47
Vested	(10,286)		79.89
Forfeited	(187)		78.89
Issued and outstanding at December 31	44,439		81.45

Grant Value Of Restricted Stock And Units


Value of restricted stock and units	2014	2013	2012
Grant price (dollars)	95.20	94.47	87.24

Value at date of grant:	(millions of dollars)
Restricted stock and units settled in stock	858	843	797
Units settled in cash	73	76	77
Total value	931	919	874

Litigation And Other Contingencies (Tables)

12 Months Ended

Dec. 31, 2014

Litigation And Other Contingencies [Abstract]

Schedule Of Guarantees

						Dec. 31, 2014
			Equity Company		Other Third-Party
			Obligations (1)		Obligations		Total
					(millions of dollars)
Guarantees
	Debt-related			3,506		41	3,547
	Other			2,920		3,982	6,902
		Total		6,426		4,023	10,449

(1) ExxonMobil share.

Unconditional Purchase Obligations

	Payments Due by Period
		2016-	2020 and
	2015	2019	Beyond		Total
	(millions of dollars)

Unconditional purchase obligations (1)	150	608		337	1,095

Pension And Other Postretirement Benefits (Tables)

12 Months Ended

Dec. 31, 2014

Pension And Other Postretirement Benefits [Abstract]

Change In Benefit Obligation Of Pension And Other Postretirement Benefits

		Pension Benefits				Other Postretirement
		U.S.		Non-U.S.		Benefits
		2014	2013	2014	2013	2014	2013
		(percent)
Weighted-average assumptions used to determine
	benefit obligations at December 31
	Discount rate	4.00	5.00	3.10	4.30	4.00	5.00
	Long-term rate of compensation increase	5.75	5.75	5.30	5.40	5.75	5.75

		(millions of dollars)
Change in benefit obligation
	Benefit obligation at January 1	17,304	19,779	27,357	28,670	7,868	9,058
	Service cost	677	801	590	697	140	176
	Interest cost	807	749	1,138	1,076	383	352
	Actuarial loss/(gain)	3,192	(1,520)	4,929	(1,454)	1,522	(1,267)
	Benefits paid (1) (2)	(1,427)	(2,520)	(1,366)	(1,311)	(525)	(511)
	Foreign exchange rate changes	-	-	(2,540)	(284)	(48)	(43)
	Amendments, divestments and other	(24)	15	(61)	(37)	96	103
Benefit obligation at December 31		20,529	17,304	30,047	27,357	9,436	7,868
Accumulated benefit obligation at December 31		16,385	13,989	26,318	23,949	-	-

(1) Benefit payments for funded and unfunded plans.

(2) For 2014 and 2013, other postretirement benefits paid are net of $21 million and $20 million of Medicare subsidy receipts, respectively.

Change In Plan Assets Of Pension And Other Postretirement Benefits

		Pension Benefits				Other Postretirement
		U.S.		Non-U.S.		Benefits
		2014	2013	2014	2013	2014	2013
		(millions of dollars)
Change in plan assets
	Fair value at January 1	11,190	12,632	19,283	18,090	620	581
	Actual return on plan assets	1,497	617	3,153	1,604	41	64
	Foreign exchange rate changes	-	-	(1,738)	(270)	-	-
	Company contribution	1,476	101	554	919	31	35
	Benefits paid (1)	(1,248)	(2,171)	(912)	(869)	(224)	(60)
	Other	-	11	(245)	(191)	-	-
Fair value at December 31		12,915	11,190	20,095	19,283	468	620

(1) Benefit payments for funded plans.

Summary Of Assets In Excess Of/(Less Than) Benefit Obligation

		Pension Benefits
		U.S.		Non-U.S.
		2014	2013	2014	2013
		(millions of dollars)
Assets in excess of/(less than) benefit obligation
	Balance at December 31
	Funded plans	(4,590)	(3,547)	(2,113)	(941)
	Unfunded plans	(3,024)	(2,567)	(7,839)	(7,133)
Total		(7,614)	(6,114)	(9,952)	(8,074)

Amounts Recorded In Balance Sheet And Other Comprehensive Income

		Pension Benefits				Other Postretirement
		U.S.		Non-U.S.		Benefits
		2014	2013	2014	2013	2014	2013
		(millions of dollars)
Assets in excess of/(less than) benefit obligation
	Balance at December 31 (1)	(7,614)	(6,114)	(9,952)	(8,074)	(8,968)	(7,248)

Amounts recorded in the consolidated balance
	sheet consist of:
	Other assets	-	1	302	201	-	-
	Current liabilities	(340)	(275)	(325)	(358)	(369)	(359)
	Postretirement benefits reserves	(7,274)	(5,840)	(9,929)	(7,917)	(8,599)	(6,889)
Total recorded		(7,614)	(6,114)	(9,952)	(8,074)	(8,968)	(7,248)

Amounts recorded in accumulated other
	comprehensive income consist of:
	Net actuarial loss/(gain)	6,589	4,780	9,642	7,943	2,997	1,603
	Prior service cost	27	60	429	665	51	65
Total recorded in accumulated other
	comprehensive income	6,616	4,840	10,071	8,608	3,048	1,668

(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

										Other
				Pension Benefits						Postretirement
				U.S.			Non-U.S.			Benefits
				2014	2013	2012	2014	2013	2012	2014	2013	2012
Weighted-average assumptions used to
	determine net periodic benefit cost for
	years ended December 31		(percent)
	Discount rate			5.00	4.00	5.00	4.30	3.80	4.00	5.00	4.00	5.00
	Long-term rate of return on funded assets			7.25	7.25	7.25	6.30	6.40	6.60	7.25	7.25	7.25
	Long-term rate of compensation increase			5.75	5.75	5.75	5.40	5.50	5.40	5.75	5.75	5.75

Components of net periodic benefit cost				(millions of dollars)
	Service cost			677	801	665	590	697	648	140	176	134
	Interest cost			807	749	820	1,138	1,076	1,145	383	352	380
	Expected return on plan assets			(799)	(835)	(789)	(1,193)	(1,128)	(1,109)	(37)	(41)	(38)
	Amortization of actuarial loss/(gain)			409	646	576	628	852	844	116	228	170
	Amortization of prior service cost			8	7	7	120	117	117	14	21	34
	Net pension enhancement and
	curtailment/settlement cost (1)			276	723	333	-	22	1,540	-	-	-
Net periodic benefit cost				1,378	2,091	1,612	1,283	1,636	3,185	616	736	680

	(1)	Non-U.S. net pension enhancement and curtailment/settlement cost for 2012 includes $1,420 million (on a consolidated-company, before-tax basis) of accumulated other comprehensive income for the postretirement benefit reserves adjustment that was recycled into earnings and included in the Japan restructuring gain reported in “Other income”.




Changes in amounts recorded in accumulated
	other comprehensive income:
	Net actuarial loss/(gain)			2,494	(1,302)	1,885	2,969	(1,938)	1,906	1,518	(1,290)	1,008
	Amortization of actuarial (loss)/gain			(685)	(1,369)	(909)	(628)	(874)	(2,384)	(116)	(228)	(170)
	Prior service cost/(credit)			(25)	-	-	(70)	30	71	-	-	-
	Amortization of prior service (cost)/credit			(8)	(7)	(7)	(120)	(117)	(117)	(14)	(21)	(34)
	Foreign exchange rate changes			-	-	-	(688)	(155)	271	(8)	(10)	3
Total recorded in other comprehensive income				1,776	(2,678)	969	1,463	(3,054)	(253)	1,380	(1,549)	807
Total recorded in net periodic benefit cost and
	other comprehensive income, before tax			3,154	(587)	2,581	2,746	(1,418)	2,932	1,996	(813)	1,487

Summary Of Change In Accumulated Other Comprehensive Income

		Total Pension and
		Other Postretirement Benefits
		2014	2013	2012
		(millions of dollars)
(Charge)/credit to other comprehensive income, before tax
	U.S. pension	(1,776)	2,678	(969)
	Non-U.S. pension	(1,463)	3,054	253
	Other postretirement benefits	(1,380)	1,549	(807)
Total (charge)/credit to other comprehensive income, before tax		(4,619)	7,281	(1,523)
(Charge)/credit to income tax (see Note 4)		1,549	(2,336)	393
(Charge)/credit to investment in equity companies		(81)	49	(49)
(Charge)/credit to other comprehensive income including noncontrolling
	interests, after tax	(3,151)	4,994	(1,179)
Charge/(credit) to equity of noncontrolling interests		85	(279)	(124)
(Charge)/credit to other comprehensive income attributable to ExxonMobil		(3,066)	4,715	(1,303)

Fair Value Of The Benefit Plan Assets (Pension)

			U.S. Pension									Non-U.S. Pension
			Fair Value Measurement									Fair Value Measurement
			at December 31, 2014, Using:									at December 31, 2014, Using:
				Quoted									Quoted
				Prices									Prices
				in Active	Significant								in Active		Significant
			Markets for			Other		Significant				Markets for				Other		Significant
				Identical	Observable			Unobservable					Identical		Observable			Unobservable
				Assets		Inputs			Inputs				Assets			Inputs			Inputs
				(Level 1)		(Level 2)			(Level 3)		Total		(Level 1)			(Level 2)			(Level 3)		Total
				(millions of dollars)
Asset category:
	Equity securities
		U.S.		-		2,331	(1)		-		2,331		-			3,284	(1)		-		3,284
		Non-U.S.		-		2,144	(1)		-		2,144		229	(2)		3,776	(1)		-		4,005
	Private equity			-		-			562	(3)	562		-			-			535	(3)	535
	Debt securities
		Corporate		-		4,841	(4)		-		4,841		-			2,686	(4)		-		2,686
		Government		-		2,890	(4)		-		2,890		249	(5)		9,050	(4)		-		9,299
		Asset-backed		-		5	(4)		-		5		-			146	(4)		-		146
	Real estate funds			-		-			-		-		-			-			57	(6)	57
	Cash			-		131	(7)		-		131		25			31	(8)		-		56
Total at fair value				-		12,342			562		12,904		503			18,973			592		20,068
	Insurance contracts
		at contract value									11										27
Total plan assets											12,915										20,095

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

(7) For cash balances held in the form of short-term fund units that are redeemable at the measurement date, the fair value is treated as a Level 2 input.

(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									Fair Value Measurement
			at December 31, 2013, Using:									at December 31, 2013, Using:
				Quoted									Quoted
				Prices									Prices
				in Active	Significant								in Active		Significant
			Markets for			Other		Significant				Markets for				Other		Significant
				Identical	Observable			Unobservable					Identical		Observable			Unobservable
				Assets		Inputs			Inputs				Assets			Inputs			Inputs
				(Level 1)		(Level 2)			(Level 3)		Total		(Level 1)			(Level 2)			(Level 3)		Total
			(millions of dollars)
Asset category:
	Equity securities
		U.S.		-		2,514	(1)		-		2,514		-			3,046	(1)		-		3,046
		Non-U.S.		-		2,622	(1)		-		2,622		294	(2)		5,608	(1)		-		5,902
	Private equity			-		-			523	(3)	523		-			-			502	(3)	502
	Debt securities
		Corporate		-		3,430	(4)		-		3,430		-			2,125	(4)		-		2,125
		Government		-		2,056	(4)		-		2,056		272	(5)		7,100	(4)		-		7,372
		Asset-backed		-		6	(4)		-		6		-			103	(4)		-		103
	Real estate funds			-		-			-		-		-			-			136	(6)	136
	Cash			-		27	(7)		-		27		57			20	(8)		-		77
Total at fair value				-		10,655			523		11,178		623			18,002			638		19,263
	Insurance contracts
		at contract value									12										20
Total plan assets											11,190										19,283

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

(7) For cash balances held in the form of short-term fund units that are redeemable at the measurement date, the fair value is treated as a Level 2 input.

(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, 2014, Using:
				Quoted
				Prices
				in Active	Significant
				Markets for	Other		Significant
				Identical	Observable		Unobservable
				Assets	Inputs		Inputs
				(Level 1)	(Level 2)		(Level 3)		Total
				(millions of dollars)
Asset category:
	Equity securities
		U.S.		-	106	(1)	-		106
		Non-U.S.		-	75	(1)	-		75
	Private equity			-	-		2	(2)	2
	Debt securities
		Corporate		-	103	(3)	-		103
		Government		-	171	(3)	-		171
		Asset-backed		-	9	(3)	-		9
	Cash			-	2		-		2
Total at fair value				-	466		2		468

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.
For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings.
For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions.

			Other Postretirement
			Fair Value Measurement
			at December 31, 2013, Using:
				Quoted
				Prices
				in Active	Significant
				Markets for	Other		Significant
				Identical	Observable		Unobservable
				Assets	Inputs		Inputs
				(Level 1)	(Level 2)		(Level 3)		Total
			(millions of dollars)
Asset category:
	Equity securities
		U.S.		-	157	(1)	-		157
		Non-U.S.		-	149	(1)	-		149
	Private equity			-	-		9	(2)	9
	Debt securities
		Corporate		-	129	(3)	-		129
		Government		-	168	(3)	-		168
		Asset-backed		-	4	(3)	-		4
	Cash			-	4		-		4
Total at fair value				-	611		9		620

(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.

Change In Fair Value Of Level 3 Assets

	2014
	Pension			Other
	U.S.	Non-U.S.		Postretirement

	Private	Private	Real	Private
	Equity	Equity	Estate	Equity
	(millions of dollars)

Fair value at January 1	523	502	136	9
Net realized gains/(losses)	2	23	(17)	-
Net unrealized gains/(losses)	89	31	8	-
Net purchases/(sales)	(52)	(21)	(70)	(7)
Fair value at December 31	562	535	57	2

	2013
	Pension			Other
	U.S.	Non-U.S.		Postretirement
	Private	Private	Real	Private
	Equity	Equity	Estate	Equity
	(millions of dollars)

Fair value at January 1	489	448	293	7
Net realized gains/(losses)	(1)	11	(13)	-
Net unrealized gains/(losses)	86	57	10	3
Net purchases/(sales)	(51)	(14)	(154)	(1)
Fair value at December 31	523	502	136	9

Pension Plans With Accumulated Benefit Obligation In Excess Of Plan Assets

		Pension Benefits
		U.S.			Non-U.S.
			2014	2013		2014	2013
		(millions of dollars)
For funded pension plans with an accumulated benefit obligation
	in excess of plan assets:
	Projected benefit obligation		17,505	14,737		5,031	891
	Accumulated benefit obligation		14,493	12,342		4,590	689
	Fair value of plan assets		12,915	11,189		3,890	611

For unfunded pension plans:
	Projected benefit obligation		3,024	2,567		7,839	7,133
	Accumulated benefit obligation		1,892	1,647		6,573	6,070

Estimated Next Year Amortization

					Other
		Pension Benefits			Postretirement
		U.S.		Non-U.S.	Benefits
		(millions of dollars)
Estimated 2015 amortization from accumulated other comprehensive income:
	Net actuarial loss/(gain) (1)		1,001	753		211
	Prior service cost (2)		6	105		14

(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 Contributions and Benefit Payments for Pension Benefits And Other Postretirement Benefits

		Pension Benefits		Other Postretirement Benefits
					Medicare
		U.S.	Non-U.S.	Gross	Subsidy Receipt
		(millions of dollars)

Contributions expected in 2015		-	560	-		-
Benefit payments expected in:
	2015	1,628	1,194	467		24
	2016	1,554	1,213	479		25
	2017	1,529	1,278	490		26
	2018	1,445	1,298	499		28
	2019	1,410	1,339	507		29
	2020 - 2024	6,714	6,988	2,613		172

Disclosures About Segments And Related Information (Tables)

12 Months Ended

Dec. 31, 2014

Disclosures About Segments And Related Information [Abstract]

Disclosures About Segments And Related Information

													Corporate
	Upstream				Downstream				Chemical					and	Corporate
	U.S.		Non-U.S.		U.S.		Non-U.S.		U.S.		Non-U.S.		Financing			Total
		(millions of dollars)
As of December 31, 2014
Earnings after income tax		5,197		22,351		1,618		1,427		2,804		1,511		(2,388)		32,520
Earnings of equity companies included above		1,235		10,859		29		82		186		1,377		(445)		13,323
Sales and other operating revenue (1)		14,826		22,336		118,771		199,976		15,115		23,063		18		394,105
Intersegment revenue		7,723		38,846		17,281		44,231		10,117		8,098		274		-
Depreciation and depletion expense		5,139		8,523		654		1,228		370		645		738		17,297
Interest revenue		-		-		-		-		-		-		75		75
Interest expense		40		17		6		4		-		-		219		286
Income taxes		1,300		15,165		610		968		1,032		358		(1,418)		18,015
Additions to property, plant and equipment		9,098		19,225		1,050		1,356		1,564		564		1,399		34,256
Investments in equity companies		5,089		10,877		69		1,006		258		3,026		(308)		20,017
Total assets		92,555		161,033		18,371		33,299		8,798		18,449		16,988		349,493

As of December 31, 2013
Earnings after income tax		4,191		22,650		2,199		1,250		2,755		1,073		(1,538)		32,580
Earnings of equity companies included above		1,576		11,627		(460)		22		189		1,422		(449)		13,927
Sales and other operating revenue (1)		13,712		25,349		123,802		218,904		15,295		23,753		21		420,836
Intersegment revenue		8,343		45,761		20,781		52,624		11,993		8,232		285		-
Depreciation and depletion expense		5,170		8,277		633		1,390		378		632		702		17,182
Interest revenue		-		-		-		-		-		-		87		87
Interest expense		30		26		7		8		1		-		(63)		9
Income taxes		2,197		21,554		721		481		989		363		(2,042)		24,263
Additions to property, plant and equipment		7,480		26,075		616		1,072		840		272		1,386		37,741
Investments in equity companies		4,975		9,740		62		1,749		217		3,103		(227)		19,619
Total assets		88,698		157,465		19,261		40,661		7,816		19,659		13,248		346,808

As of December 31, 2012
Earnings after income tax		3,925		25,970		3,575		9,615		2,220		1,678		(2,103)		44,880
Earnings of equity companies included above		1,759		11,900		6		387		183		1,267		(492)		15,010
Sales and other operating revenue (1)		11,039		27,673		125,088		248,959		14,723		24,003		24		451,509
Intersegment revenue		8,764		47,507		20,963		62,130		12,409		9,750		258		-
Depreciation and depletion expense		5,104		7,340		594		1,280		376		508		686		15,888
Interest revenue		-		-		-		-		-		-		117		117
Interest expense		37		13		3		36		-		(1)		239		327
Income taxes		2,025		25,362		1,811		1,892		755		232		(1,032)		31,045
Additions to property, plant and equipment		9,697		21,769		480		1,153		338		659		1,083		35,179
Investments in equity companies		4,020		9,147		195		2,069		233		3,143		(277)		18,530
Total assets		86,146		140,848		18,451		40,956		7,238		18,886		21,270		333,795

(1) Sales and other operating revenue includes sales-based taxes of $29,342 million for 2014, $30,589 million for 2013 and $32,409 million for 2012. See Note 1, Summary of Accounting Policies.

Geographic Sales And Other Operating Revenue

Geographic

Sales and other operating revenue (1)		2014	2013	2012
		(millions of dollars)

United States		148,713	152,820	150,865
Non-U.S.		245,392	268,016	300,644
	Total	394,105	420,836	451,509

Significant non-U.S. revenue sources include:
	Canada	36,072	35,924	34,325
	United Kingdom	31,346	34,061	33,600
	Belgium	20,953	20,973	23,567
	Italy	18,880	19,273	18,228
	France	17,639	18,444	19,601
	Singapore	15,407	15,623	14,606
	Germany	14,816	15,701	15,871

(1) Sales and other operating revenue includes sales-based taxes of $29,342 million for 2014, $30,589 million for 2013 and $32,409 million for 2012. See Note 1, Summary of Accounting Policies.

Schedule Of Long-Lived Assets By Geographic Regions

Long-lived assets		2014	2013	2012
		(millions of dollars)

United States		104,000	98,271	94,336
Non-U.S.		148,668	145,379	132,613
	Total	252,668	243,650	226,949

Significant non-U.S. long-lived assets include:
	Canada	43,858	41,522	31,979
	Australia	15,328	14,258	13,415
	Nigeria	12,265	12,343	12,216
	Singapore	9,620	9,570	9,700
	Kazakhstan	9,138	8,530	7,785
	Angola	9,057	8,262	8,238
	Papua New Guinea	6,099	5,768	4,599
	Norway	5,139	6,542	7,040

Income, Sales-Based And Other Taxes (Tables)

12 Months Ended

Dec. 31, 2014

Income, Sales-Based And Other Taxes [Abstract]

Schedule Of Income, Sales-Based And Other Taxes

						2014				2013				2012
				U.S.	Non-U.S.		Total	U.S.	Non-U.S.		Total	U.S.	Non-U.S.		Total
								(millions of dollars)
Income tax expense
	Federal and non-U.S.
		Current		1,456		14,755	16,211	1,073		22,115	23,188	1,791		25,650	27,441
		Deferred - net		900		1,398	2,298	(116)		757	641	1,097		1,816	2,913
	U.S. tax on non-U.S. operations			5		-	5	37		-	37	89		-	89
			Total federal and non-U.S.	2,361		16,153	18,514	994		22,872	23,866	2,977		27,466	30,443
	State (1)			(499)		-	(499)	397		-	397	602		-	602
			Total income tax expense	1,862		16,153	18,015	1,391		22,872	24,263	3,579		27,466	31,045
Sales-based taxes				6,310		23,032	29,342	5,992		24,597	30,589	5,785		26,624	32,409
All other taxes and duties
	Other taxes and duties			378		31,908	32,286	955		32,275	33,230	1,406		34,152	35,558
	Included in production and
		manufacturing expenses		1,454		1,179	2,633	1,318		1,182	2,500	1,242		1,308	2,550
	Included in SG&A expenses			155		441	596	150		516	666	154		595	749
		Total other taxes and duties		1,987		33,528	35,515	2,423		33,973	36,396	2,802		36,055	38,857
			Total	10,159		72,713	82,872	9,806		81,442	91,248	12,166		90,145	102,311

(1) In 2014, state taxes included a favorable adjustment of deferred taxes of approximately $830 million.

Reconciliation Between Income Tax Expense And A Theoretical U.S. Tax

			2014	2013	2012
			(millions of dollars)
Income before income taxes
	United States		9,080	9,746	11,222
	Non-U.S.		42,550	47,965	67,504
		Total	51,630	57,711	78,726
Theoretical tax			18,071	20,199	27,554
Effect of equity method of accounting			(4,663)	(4,874)	(5,254)
Non-U.S. taxes in excess of theoretical U.S. tax			5,442	10,528	8,434
U.S. tax on non-U.S. operations			5	37	89
State taxes, net of federal tax benefit			(324)	258	391
Other			(516)	(1,885)	(169)
		Total income tax expense	18,015	24,263	31,045

Effective tax rate calculation
Income taxes			18,015	24,263	31,045
ExxonMobil share of equity company income taxes			5,678	6,061	5,859
		Total income taxes	23,693	30,324	36,904
Net income including noncontrolling interests			33,615	33,448	47,681
		Total income before taxes	57,308	63,772	84,585

Effective income tax rate			41%	48%	44%

Deferred Tax Liabilities/(Assets)

Tax effects of temporary differences for:		2014	2013
		(millions of dollars)

Property, plant and equipment		51,643	50,884
Other liabilities		4,359	3,474
	Total deferred tax liabilities	56,002	54,358

Pension and other postretirement benefits		(8,140)	(6,573)
Asset retirement obligations		(6,162)	(6,083)
Tax loss carryforwards		(4,099)	(3,393)
Other assets		(6,446)	(6,246)
	Total deferred tax assets	(24,847)	(22,295)

Asset valuation allowances		2,570	2,491
	Net deferred tax liabilities	33,725	34,554

Deferred Income Tax (Assets) And Liabilities By Balance Sheet Classification

Balance sheet classification		2014	2013
		(millions of dollars)

Other current assets		(2,001)	(3,575)
Other assets, including intangibles, net		(3,955)	(2,822)
Accounts payable and accrued liabilities		451	421
Deferred income tax liabilities		39,230	40,530
	Net deferred tax liabilities	33,725	34,554

Unrecognized Tax Benefits

Gross unrecognized tax benefits		2014	2013	2012
		(millions of dollars)

Balance at January 1		7,838	7,663	4,922
	Additions based on current year's tax positions	1,454	1,460	1,662
	Additions for prior years' tax positions	448	464	2,559
	Reductions for prior years' tax positions	(532)	(249)	(535)
	Reductions due to lapse of the statute of limitations	(117)	(588)	(79)
	Settlements with tax authorities	(43)	(849)	(855)
	Foreign exchange effects/other	(62)	(63)	(11)
Balance at December 31		8,986	7,838	7,663

Remaining Tax Years Subject To Examination By Major Tax Jurisdiction

	Country of Operation	Open Tax Years
	Abu Dhabi	2012 - 2014
	Angola	2009 - 2014
	Australia:	2000 - 2003
		2005
		2008 - 2014
	Canada	2007 - 2014
	Equatorial Guinea	2007 - 2014
	Malaysia	2008 - 2014
	Nigeria	2004 - 2014
	Norway	2005 - 2014
	Qatar	2008 - 2014
	Russia	2011 - 2014
	United Kingdom	2010 - 2014
	United States	2006 - 2014

Miscellaneous Financial Information (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Miscellaneous Financial Information [Abstract]
Research and development expense	$ 971,000,000	$ 1,044,000,000	$ 1,042,000,000
Foreign currency transaction gain/(loss), before tax	(225,000,000)	155,000,000	159,000,000
Gains on combined effects of LIFO inventory accumulations and draw-downs	187,000,000	282,000,000	$ 328,000,000
Replacement cost of inventories estimated to exceed LIFO carrying values	$ 10,600,000,000	$ 21,200,000,000

Miscellaneous Financial Information (Crude Oil, Products And Merchandise) (Details) - USD ($) $ in Millions	Dec. 31, 2014	Dec. 31, 2013
Miscellaneous Financial Information [Abstract]
Petroleum products	$ 4,100	$ 3,900
Crude oil	4,600	4,700
Chemical products	2,900	2,900
Gas / other	800	600
Total	$ 12,384	$ 12,117

Other Comprehensive Income Information (Schedule of Accumulated Other Comprehensive Income Information) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current period change excluding amounts reclassified from accumulated other comprehensive income, Cumulative Foreign Exchange Translation Adjustment	$ (5,847)	$ (3,620)	$ 920
Amounts reclassified from accumulated other comprehensive income, Cumulative Foreign Exchange Translation Adjustment	152	(23)	(4,352)
Current period change excluding amounts reclassified from accumulated other comprehensive income, Postretirement Benefits Reserves Adjustment	(4,262)	3,174	(3,574)
Amounts reclassified from accumulated other comprehensive income, Postretirement Benefits Reserves Adjustment	1,111	1,820	2,395
Current period change excluding amounts reclassified from accumulated other comprehensive income, Unrealized Change in Stock Investments	(63)
Amounts reclassified from accumulated other comprehensive income, Unrealized Change in Stock Investments	3
Beginning Balance, Total	(10,725)
Total other comprehensive income	(8,906)	1,351	(4,611)
Ending Balance, Total	(18,957)	(10,725)
Exxon Mobil Corporation Share After Noncontrolling Interest [Member]
Beginning Balance, Cumulative Foreign Exchange Translation Adjustment	(846)	2,410	4,168
Current period change excluding amounts reclassified from accumulated other comprehensive income, Cumulative Foreign Exchange Translation Adjustment	(5,258)	(3,233)	842
Amounts reclassified from accumulated other comprehensive income, Cumulative Foreign Exchange Translation Adjustment	152	(23)	(2,600)
Total change in accumulated other comprehensive income, Cumulative Foreign Exchange Translation Adjustment	(5,106)	(3,256)	(1,758)
Ending Balance, Cumulative Foreign Exchange Translation Adjustment	(5,952)	(846)	2,410
Beginning Balance, Postretirement Benefits Reserves Adjustment	(9,879)	(14,594)	(13,291)
Current period change excluding amounts reclassified from accumulated other comprehensive income, Postretirement Benefits Reserves Adjustment	(4,132)	2,963	(3,402)
Amounts reclassified from accumulated other comprehensive income, Postretirement Benefits Reserves Adjustment	1,066	1,752	2,099
Total change in accumulated other comprehensive income, Postretirement Benefits Reserves Adjustment	(3,066)	4,715	(1,303)
Ending Balance, Postretirement Benefits Reserves Adjustment	(12,945)	(9,879)	(14,594)
Current period change excluding amounts reclassified from accumulated other comprehensive income, Unrealized Change in Stock Investments	(63)
Amounts reclassified from accumulated other comprehensive income, Unrealized Change in Stock Investments	3
Total change in accumulated other comprehensive income, Unrealized Change in Stock Investments	(60)
Ending Balance, Unrealized Change in Stock Investments	(60)
Beginning Balance, Total	(10,725)	(12,184)	(9,123)
Current period change excluding amounts reclassified from accumulated other comprehensive income, Total	(9,453)	(270)	(2,560)
Amounts reclassified from accumulated other comprehensive income, Total	1,221	1,729	(501)
Total other comprehensive income	(8,232)	1,459	(3,061)
Ending Balance, Total	$ (18,957)	$ (10,725)	$ (12,184)

Other Comprehensive Income Information (Amounts Reclassified Out Of Acc Other Comp Income) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Accumulated Foreign Exchange Translation Adjustment [Member]

Foreign exchange translation gain/(loss) included in net income (Statement of Income line: Other Income)

$ (152)

$ 23

$ 4,352

Accumulated Defined Benefit Plans Adjustment [Member]

Amortization and settlement of postretirement benefits reserves adjustment included in net periodic benefit costs

^[1]

(1,571)

$ (2,616)

$ (3,621)

Accumulated Net Unrealized Investment Gain Loss [Member]

Realized change in fair value of stock investments included in net income (Statement of Income line: Other income)

$ (5)

[1]	These accumulated other comprehensive income components are included in the computation of net periodic pension cost. (See Note 17 – Pension and Other Postretirement Benefits for additional details.)

Other Comprehensive Income Information (Schedule Of Income Tax (Expense)/Credit For Components Of Other Comprehensive Income) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Other Comprehensive Income Information Tax [Abstract]
Foreign exchange translation adjustment	$ 292	$ 218	$ (236)
Postretirement benefits reserves adjustment (excluding amortization)	2,009	(1,540)	1,619
Amortization and settlement of postretirement benefits reserves adjustment included in net periodic benefit costs	(460)	(796)	(1,226)
Unrealized change in fair value of stock investments	34
Realized change in fair value of stock investments included in net income	(2)
Total	$ 1,873	$ (2,118)	$ 157

Cash Flow Information (Cash Payments For Interest And Income Taxes) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash Flow Information [Abstract]
Cash payments for interest	$ 380	$ 426	$ 555
Cash payments for income taxes	18,085	$ 25,066	24,349
Asset exchanges, primarily noncash	$ 1,200		$ 1,000

Additional Working Capital Information (Narrative) (Details) - USD ($) $ in Billions	Dec. 31, 2014	Dec. 31, 2013
Line Of Credit Facility [Line Items]
Weighted-average interest rate on short-term borrowings outstanding	0.30%	0.40%
Short Term Financing [Member]
Line Of Credit Facility [Line Items]
Unused credit lines	$ 6.3

Additional Working Capital Information (Schedule Of Notes, Accounts Receivable And Payable, Loans Payable, Accrued Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2014	Dec. 31, 2013
Additional Working Capital Information [Abstract]
Trade notes and accounts receivable, less reserves of $113 million and $112 million	$ 18,541	$ 25,993
Other notes and accounts receivable, less reserves of $48 million and $28 million	9,468	7,159
Total notes and accounts receivable	28,009	33,152
Bank loans	473	723
Commercial paper	16,225	14,051
Long-term debt due within one year	770	1,034
Total notes and loans payable	17,468	15,808
Trade payables	25,286	30,920
Payables to equity companies	6,589	6,587
Accrued taxes other than income taxes	3,290	3,883
Other accounts payable and accrued liabilities	7,062	6,695
Total accounts payable and accrued liabilities	42,227	48,085
Trade notes and accounts receivable, reserves	113	112
Other notes and accounts receivable, reserves	$ 48	$ 28

Equity Company Information (Narrative) (Details) - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Schedule of Equity Method Investments [Line Items]
Share of equity company sales revenues from sales to consolidated companies	14.00%	13.00%	16.00%
Rosneft VIE Joint Venture [Member]
Schedule of Equity Method Investments [Line Items]
Maximum Exposure to Loss from Rosneft JV's	$ 1

Equity Company Information (Schedule Of Equity Company Financial Summary) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Subsidiary or Equity Method Investee [Line Items]
Net assets	$ 20,017	$ 19,619	$ 18,530
ExxonMobil Share Of Equity [Member]
Subsidiary or Equity Method Investee [Line Items]
Total revenues	55,855	68,084	67,572
Income before income taxes	19,014	19,999	20,882
Income taxes	5,684	6,069	5,868
Income from equity affiliates	13,330	13,930	15,014
Current assets	16,802	19,545	18,483
Long-term assets	33,619	35,695	33,798
Total assets	50,421	55,240	52,281
Current liabilities	11,472	15,243	14,265
Long-term liabilities	19,470	20,873	19,715
Net assets	19,479	19,124	18,301
Total Equity Company Including All Owners [Member]
Subsidiary or Equity Method Investee [Line Items]
Total revenues	183,708	236,161	224,953
Income before income taxes	65,549	69,454	69,411
Income taxes	20,520	21,618	20,703
Income from equity affiliates	45,029	47,836	48,708
Current assets	49,905	62,398	59,612
Long-term assets	110,754	116,450	111,131
Total assets	160,659	178,848	170,743
Current liabilities	37,333	54,550	49,698
Long-term liabilities	66,231	68,857	68,855
Net assets	$ 57,095	$ 55,441	$ 52,190

Equity Company Information (Schedule Of The Corporation's Percentage Ownership Interest) (Details)	Dec. 31, 2014
Upstream [Member] \| Aera Energy LLC [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	48.00%
Upstream [Member] \| BEB Erdgas und Erdoel GmbH & Co. KG [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	50.00%
Upstream [Member] \| Cameroon Oil Transportation Company S.A. [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	41.00%
Upstream [Member] \| Cross Timbers Energy, LLC [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	50.00%
Upstream [Member] \| Golden Pass LNG Terminal LLC [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	18.00%
Upstream [Member] \| Karmorneftegaz Holding SARL [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	33.00%
Upstream [Member] \| Marine Well Containment Company LLC [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	10.00%
Upstream [Member] \| Nederlandse Aardolie Maatschappij B.V. [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	50.00%
Upstream [Member] \| Qatar Liquefied Gas Company Limited [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	10.00%
Upstream [Member] \| Qatar Liquefied Gas Company Limited (2) [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	24.00%
Upstream [Member] \| Ras Laffan Liquefied Natural Gas Company Limited [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	25.00%
Upstream [Member] \| Ras Laffan Liquefied Natural Gas Company Limited (II) [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	31.00%
Upstream [Member] \| Ras Laffan Liquefied Natural Gas Company Limited (3) [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	30.00%
Upstream [Member] \| South Hook LNG Terminal Company Limited [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	24.00%
Upstream [Member] \| Tengizchevroil, LLP [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	25.00%
Upstream [Member] \| Terminale GNL Adriatico S.r.l. [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	71.00%
Downstream [Member] \| Chalmette Refining, LLC [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	50.00%
Downstream [Member] \| Fujian Refining & Petrochemical Co. Ltd. [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	25.00%
Downstream [Member] \| Saudi Aramco Mobil Refinery Company Ltd. [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	50.00%
Chemical [Member] \| Al-Jubail Petrochemical Company [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	50.00%
Chemical [Member] \| Infineum Holdings B.V. [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	50.00%
Chemical [Member] \| Infineum USA L.P. [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	50.00%
Chemical [Member] \| Saudi Yanbu Petrochemical Co. [Member]
Subsidiary or Equity Method Investee [Line Items]
Percentage Ownership Interest	50.00%

Investments, Advances And Long-Term Receivables (Details) - USD ($) $ in Millions	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Investments, Advances And Long-Term Receivables [Abstract]
Investments (Companies carried at equity in underlying assets)	$ 20,017	$ 19,619	$ 18,530
Advances (Companies carried at equity in underlying assets)	9,818	10,476
Total equity company investments and advances	29,835	30,095
Companies carried at cost or less and stock investments carried at fair value	526	115
Long-term receivables and miscellaneous investments at cost or less, net of reserves of $2,662 million and $2,938 million	4,878	6,118
Total	35,239	36,328
Reserves for long-term receivables and miscellaneous investments	$ 2,662	$ 2,938

Property, Plant And Equipment And Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Property, Plant and Equipment [Line Items]
Accumulated depreciation and depletion	$ 194,121	$ 190,867
Interest capitalized	$ 344	$ 309	$ 506
Downstream [Member] \| Refinery And Lubes Basestock Manufacturing Facilities [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life of equipment, years	25 years
Downstream [Member] \| Service Station Buildings And Fixed Improvements [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life of equipment, years	20 years
Chemical [Member] \| Investments In Process Equipment [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life of equipment, years	20 years

Property, Plant And Equipment And Asset Retirement Obligations (Property, Plant And Equipment) (Details) - USD ($) $ in Millions	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	$ 446,789	$ 434,517
Property, Plant and Equipment, Net	252,668	243,650	$ 226,949
Upstream [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	347,170	336,359
Property, Plant and Equipment, Net	205,308	197,554
Downstream [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	53,327	54,456
Property, Plant and Equipment, Net	22,639	23,219
Chemical [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	30,717	29,487
Property, Plant and Equipment, Net	14,918	13,965
Other [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	15,575	14,215
Property, Plant and Equipment, Net	$ 9,803	$ 8,912

Property, Plant And Equipment And Asset Retirement Obligations (Asset Retirement Obligations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Property, Plant And Equipment And Asset Retirement Obligations [Abstract]
Beginning balance	$ 12,988	$ 11,973
Accretion expense and other provisions	871	785
Reduction due to property sales	(151)	(97)
Payments made	(724)	(664)
Liabilities incurred	122	603
Foreign currency translation	(908)	(344)
Revisions	1,226	732
Ending balance	$ 13,424	$ 12,988

Accounting For Suspended Exploratory Well Costs (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2014 USD ($)	Dec. 31, 2013 USD ($)	Dec. 31, 2012 USD ($)	Dec. 31, 2011 USD ($)
Exploratory Wells Drilled [Line Items]
Number of projects that have exploratory well costs capitalized for a period greater than twelve months as of December 31, 2014	53	50	45
Number of projects that have drilling in the preceding twelve months or exploratory activity planned in the next two years as of December 31, 2014	15
Number of projects with completed exploratory activity progressing toward development as of December 31, 2014	38
Capitalized exploratory well costs	$ 3,587	$ 2,707	$ 2,679	$ 2,881
Total 38 Projects [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 1,035

Accounting For Suspended Exploratory Well Costs (Change In Capitalized Suspended Exploratory Well Costs) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Accounting For Suspended Exploratory Well Costs [Abstract]
Capitalized suspended exploratory well costs, beginning balance	$ 2,707	$ 2,679	$ 2,881
Additions pending the determination of proved reserves	1,095	293	868
Charged to expense	(28)	(52)	(95)
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	(160)	(107)	(631)
Divestments/Other	(27)	(106)	(344)
Capitalized suspended exploratory well costs, ending balance	3,587	2,707	2,679
Ending balance attributed to equity companies included above	$ 645	$ 13	$ 3

Accounting For Suspended Exploratory Well Costs (Schedule Of Period End Capitalized Suspended Exploratory Well Costs) (Details) - USD ($) $ in Millions	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized for a period of one year or less	$ 1,095	$ 293	$ 866
Capitalized suspended exploratory well costs, total	3,587	2,707	2,679	$ 2,881
Capitalized For A Period Of Between One And Five Years [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized suspended exploratory well costs	1,659	1,705	1,176
Capitalized For A Period Of Between Five And Ten Years [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized suspended exploratory well costs	544	470	401
Capitalized For A Period Of Greater Than Ten Years [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized suspended exploratory well costs	289	239	236
Capitalized For A Period Greater Than One Year [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized suspended exploratory well costs	$ 2,492	$ 2,414	$ 1,813

Accounting For Suspended Exploratory Well Costs (Schedule Of Number Of Projects With Suspended Exploratory Well Costs) (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Accounting For Suspended Exploratory Well Costs [Abstract]
Number of projects with first capitalized well drilled in the preceding 12 months	8	8	10
Number of projects that have exploratory well costs capitalized for a period of greater than 12 months	53	50	45
Total	61	58	55

Leased Facilities (Narrative) (Details) $ in Millions	12 Months Ended
Leased Facilities (Narrative) (Details) $ in Millions	Dec. 31, 2014 USD ($)
Leased Facilities [Abstract]
Minimum undiscounted lease commitments	$ 6,213
Estimated related rental income from noncancelable subleases	$ 70

Leased Facilities (Leased Facilities) (Details) $ in Millions	Dec. 31, 2014 USD ($)
Leased Facilities [Abstract]
Lease Payments Under Minimum Commitments, 2015	$ 2,034
Lease Payments Under Minimum Commitments, 2016	1,379
Lease Payments Under Minimum Commitments, 2017	774
Lease Payments Under Minimum Commitments, 2018	418
Lease Payments Under Minimum Commitments, 2019	312
Lease Payments Under Minimum Commitments, 2020 and beyond	1,296
Lease Payments Under Minimum Commitments, Total	6,213
Related Sublease Rental Income, 2015	31
Related Sublease Rental Income, 2016	7
Related Sublease Rental Income, 2017	6
Related Sublease Rental Income, 2018	3
Related Sublease Rental Income, 2019	3
Related Sublease Rental Income, 2020 and beyond	20
Related Sublease Rental Income, Total	$ 70

Leased Facilities (Net Rental Cost) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Leased Facilities [Abstract]
Rental cost	$ 4,077	$ 3,841	$ 3,851
Less sublease rental income	52	44	44
Net rental cost	$ 4,025	$ 3,797	$ 3,807

Earnings Per Share (Details) - USD ($)
$ / shares in Units, shares in Millions, $ in Millions

12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Earnings per common share

Net income attributable to ExxonMobil

$ 32,520

$ 32,580

$ 44,880

Weighted average number of common shares outstanding

4,282

4,419

4,628

Earnings per common share (dollars)

^[1]

$ 7.6

$ 7.37

$ 9.7

Dividends paid per common share (dollars)

$ 2.7

$ 2.46

$ 2.18

[1]	The earnings per common share and earnings per common share - assuming dilution are the same in each period shown.

The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period.

+ References + Details

Debt Instrument, Unamortized Premium

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

+ References + Details

Financial Instruments And Derivatives (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Financial Instruments And Derivatives [Line Items]
Estimated fair value of total long-term debt, excluding capitalized lease obligations		$ 11,700	$ 6,800
Recorded book values of total long-term debt, excluding capitalized lease obligations		11,300	6,500
Derivative asset at fair value, net		75	1
Gain (loss) before-tax earnings impact of derivatives		110	(7)	$ (23)
Additions to long-term debt	$ 5,500	5,731	$ 345	$ 995
Level 1 [Member]
Financial Instruments And Derivatives [Line Items]
Estimated fair value of total long-term debt, excluding capitalized lease obligations		11,036
Level 2 [Member]
Financial Instruments And Derivatives [Line Items]
Estimated fair value of total long-term debt, excluding capitalized lease obligations		561
Level 3 [Member]
Financial Instruments And Derivatives [Line Items]
Estimated fair value of total long-term debt, excluding capitalized lease obligations		$ 63

Long-Term Debt (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term debt due in U.S. dollars		$ 11,341
U.S. dollar equivalent at year-end exchange rates of amounts payable in foreign currencies		312
Portion of long-term debt included in current liability		770	$ 1,034
Long-term debt maturing - 2016		537
Long-term debt maturing - 2017		2,993
Long-term debt maturing - 2018		872
Long-term debt maturing - 2019		2,353
Additions to long-term debt	$ 5,500	5,731	$ 345	$ 995
Long Term Financing [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Unused credit lines		$ 500

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

12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

$ 219

$ 271

Long-term debt

11,653

6,891

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

^[1]

$ 104

$ 112

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

4.20%

4.40%

0.921% Notes Due 2017 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]

$ 9

$ 1,500

0.921%

Floating-Rate Notes Due 2017 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]

Mar. 15, 2017

^[2]

$ 750

Mar. 15, 2017

1.819% Notes Due 2019 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]

0.30%

$ 1,750

1.819%

Floating-Rate Notes Due 2019 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]

Mar. 15, 2019

^[3]

$ 500

Mar. 15, 2019

3.176% Notes Due 2024 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]

0.40%

$ 1,000

3.176%

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

Mar. 15, 2024

$ 132

5.00%

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

Jan. 31, 2015

$ 243

5.30%

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

Jun. 30, 2015

$ 207

$ 212

5.65%

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

Apr. 01, 2016

$ 477

$ 489

6.25%

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

Aug. 01, 2017

$ 383

$ 389

5.50%

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

Jun. 15, 2018

$ 474

$ 485

6.50%

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

Dec. 15, 2018

$ 199

$ 200

6.10%

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

Apr. 01, 2036

$ 309

$ 312

6.75%

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

Aug. 01, 2037

$ 236

$ 238

6.375%

Variable Notes Due 2015-2019 [Member] | Mobil Producing Nigeria Unlimited [Member]

Jun. 15, 2038

Debt Instrument, maturity date range, start

^[4]

$ 399

$ 742

Jun. 15, 2016

Dec. 31, 2017

Debt Instrument, maturity date range, end

Mar. 15, 2019

Dec. 31, 2019

Variable Notes Due 2015-2019 [Member] | Esso (Thailand) Public Company Ltd. [Member]

4.50%

4.60%

Debt Instrument, maturity date range, start

^[5]

$ 121

$ 177

Nov. 30, 2017

Sep. 28, 2015

Debt Instrument, maturity date range, end

Dec. 31, 2019

Nov. 30, 2017

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

2.40%

3.30%

$ 249

8.625%

Industrial Revenue Bonds Due 2015-2051 [Member] | Combined Exxon Mobil And Affiliates [Member]

Aug. 15, 2021

Debt Instrument, maturity date range, start

^[6]

$ 2,611

$ 2,527

Apr. 01, 2017

Jul. 31, 2015

Debt Instrument, maturity date range, end

Dec. 01, 2051

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

0.03%

0.06%

7.00%

7.80%

Long-term debt

^[7]

$ 375

[1]	Average effective interest rate of 4.2% in 2014 and 4.4% in 2013.
[2]	Average effective interest rate of 0.3% in 2014.
[3]	Average effective interest rate of 0.4% in 2014.
[4]	Average effective interest rate of 4.5% in 2014 and 4.6% in 2013.
[5]	Average effective interest rate of 2.4% in 2014 and 3.3% in 2013.
[6]	Average effective interest rate of 0.03% in 2014 and 0.06% in 2013.
[7]	Average imputed interest rate of 7.0% in 2014 and 7.8% in 2013.

Incentive Program (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Minimum ownership of affiliates needed for awards	50.00%
Number of shares issuable under 2003 incentive program, maximum	220,000,000
Remaining shares available for award under 2003 incentive program	108,000,000
Options and stock appreciation rights grant, minimum percentage of market value, date of grant	100.00%
Maximum Life Per Program Member [Member]
Share-based compensation arrangement by share-based payment award expiration period	10 years
Restricted Stock [Member]
Long-term incentive awards	9,775,000	9,729,000	10,017,000
Unrecognized compensation cost	$ 2,339
Unrecognized compensation cost, weighted-average period of recognition, years	4 years 6 months
Compensation cost charged against income	$ 831	$ 854	$ 854
Income tax benefit recognized in income	76	78	79
Fair value of shares/awards vested	946	1,040	926
Cash payments, vested restricted stock units	$ 73	$ 67	$ 66
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%
Percent of shares in each award vesting after five years	50.00%
Percent of shares in each award vesting in later of ten years or retirement	50.00%
Restricted Stock [Member] \| Minimum [Member]
Vesting Period	3 years
Restricted Stock [Member] \| Minimum [Member] \| Executive Officer [Member]
Vesting Period	5 years
Restricted Stock [Member] \| Maximum [Member]
Vesting Period	7 years
Restricted Stock [Member] \| Maximum [Member] \| Executive Officer [Member]
Vesting Period	10 years

Incentive Program (Summary Of Restricted Stock And Units Outstanding) (Details) shares in Thousands	12 Months Ended
	Dec. 31, 2014 $ / shares shares
Incentive Program [Abstract]
Issued and outstanding at January 1, Restricted stock, Shares \| shares	45,207
2013 award issued in 2014, Shares \| shares	9,705
Vested, Shares \| shares	(10,286)
Forfeited, Shares \| shares	(187)
Issued and outstanding at December 31, Restricted stock, Shares \| shares	44,439
Issued and outstanding at January 1, Weighted Average Grant-Date Fair Value per Share \| $ / shares	$ 78.29
2013 award issued in 2014, Weighted Average Grant-Date Fair Value per Share \| $ / shares	94.47
Vested, Weighted Average Grant-Date Fair Value per Share \| $ / shares	79.89
Forfeited, Weighted Average Grant-Date Fair Value per Share \| $ / shares	78.89
Issued and outstanding at December 31, Weighted Average Grant-Date Fair Value per Share \| $ / shares	$ 81.45

Incentive Program (Grant Value Of Restricted Stock And Units) (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Grant price, per share	$ 95.2	$ 94.47	$ 87.24
Restricted stock and units settled in stock	$ 858	$ 843	$ 797
Units settled in cash	73	76	77
Total value	$ 931	$ 919	$ 874

Litigation And Other Contingencies (Narrative) (Details) - USD ($)	3 Months Ended
	Dec. 31, 2014	Oct. 09, 2014	Oct. 24, 2011	Jun. 27, 2007	May 01, 2007
Mobil Cerro Negro, Ltd. (MCN) [Member] \| Expropriation of Assets [Member]
Loss Contingencies [Line Items]
Percentage ownership interest in Cerro Negro Project				41.67%	41.67%
Interest compounded annually from date of expropriation until date of payment in full		3.25%
Final award related to Cerro Negro arbitration		$ 1,600,000,000
Earlier Cerro Negro award for breach of contractual obligations		$ 908,000,000
Recognized earnings net of the remaining asset value from earlier ICC award	$ 269,000,000
Production Sharing Contract (PSC) [Member]
Loss Contingencies [Line Items]
Percent interest in Erha block PSC			56.25%
Pending Or Threatened Litigation [Member]
Loss Contingencies [Line Items]
Amount of award relating to excess lifting of crude oil			$ 1,800,000,000
Accrued interest relating to award for excess lifting of crude oil			$ 234,000,000

Litigation And Other Contingencies (Schedule Of Guarantees) (Details)
$ in Millions

Dec. 31, 2014

USD ($)

Equity Company Obligations [Member]

$ 10,449

Other Third-Party Obligations [Member]

6,426

^[1]

Debt-Related Guarantees [Member]

4,023

3,547

3,400

3,506

^[1]

Other Guarantees [Member]

Other Guarantees [Member] | Equity Company Obligations [Member]

6,902

Other Guarantees [Member] | Other Third-Party Obligations [Member]

2,920

^[1]

Unrecorded Unconditional Purchase Obligation [Line Items]

$ 3,982

[1]	ExxonMobil share

Litigation And Other Contingencies (Schedule Of Unconditional Purchase Obligations) (Details)
$ in Millions

Dec. 31, 2014

USD ($)

$ 150

608

337

1,095

^[1]

Present value of these commitments

927

Undiscounted unconditional purchase obligations

1,095

^[1]

Imputed interest

168

Equity Company Obligations [Member]

Unrecorded Unconditional Purchase Obligation [Line Items]

Undiscounted unconditional purchase obligations

433

$ 433

[1]	Undiscounted obligations of $1,095 million mainly pertain to pipeline throughput agreements and include $433 million of obligations to equity companies. The present value of these commitments, which excludes imputed interest of $168 million, totaled $927 million.

Pension And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate projected in 2016	4.50%
Year that rate reaches ultimate trend rate	2016
Effect of one-percentage-point increase on service and interest costs	$ 91
Effect of one-percentage-point increase on postretirement benefit obligation	1,070
Effect of one-percentage-point decrease on service and interest costs	69
Effect of one-percentage-point decrease on postretirement benefit obligation	844
Costs for defined contribution plans	$ 393	$ 392	$ 382
Pension Benefits - U.S. [Member] \| Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation	40.00%
Pension Benefits - U.S. [Member] \| Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation	60.00%
Pension Benefits - U.S. [Member] \| Venture Capital Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation	5.00%
Pension Benefits - Non-U.S. [Member] \| Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation	40.00%
Pension Benefits - Non-U.S. [Member] \| Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation	60.00%
Pension Benefits - Non-U.S. [Member] \| Venture Capital Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation	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, 2014

Dec. 31, 2013

Dec. 31, 2012

Medicare subsidy receipts

$ 21

$ 20

4.00%

5.00%

Benefit obligation at January 1

5.75%

$ 17,304

$ 19,779

677

801

$ 665

Defined Benefit Plan, Actuarial Net (Gains) Losses

807

749

820

3,192

(1,520)

Amendments, divestments and other

(24)

Benefit obligation at December 31

20,529

17,304

19,779

Accumulated benefit obligation at December 31

$ 16,385

$ 13,989

3.10%

4.30%

Benefit obligation at January 1

5.30%

5.40%

$ 27,357

$ 28,670

590

697

648

Defined Benefit Plan, Actuarial Net (Gains) Losses

1,138

1,076

1,145

4,929

(1,454)

Amendments, divestments and other

(2,540)

(284)

(61)

(37)

Benefit obligation at December 31

30,047

27,357

28,670

Accumulated benefit obligation at December 31

$ 26,318

$ 23,949

4.00%

5.00%

Benefit obligation at January 1

5.75%

$ 7,868

$ 9,058

140

176

134

Defined Benefit Plan, Actuarial Net (Gains) Losses

383

352

380

1,522

(1,267)

Amendments, divestments and other

(48)

(43)

103

Benefit obligation at December 31

9,436

7,868

$ 9,058

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]

^[1]

(1,427)

(2,520)

Benefit Payments For Funded And Unfunded Plans [Member] | Other Postretirement Benefits [Member]

^[1]

(1,366)

(1,311)

^[1],[2]

$ (525)

$ (511)

[1]	Benefit payments for funded and unfunded plans.
[2]	For 2014 and 2013, other postretirement benefits paid are net of $21 million and $20 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, 2014

Dec. 31, 2013

Actual return on plan assets

Fair value at January 1

$ 11,190

$ 12,632

1,497

617

Company contribution

1,476

101

Other

Fair value at December 31

12,915

11,190

Actual return on plan assets

Fair value at January 1

19,283

18,090

3,153

1,604

Fair value at December 31

(1,738)

(270)

Company contribution

554

919

Other

(245)

(191)

20,095

19,283

Actual return on plan assets

Fair value at January 1

620

581

Company contribution

Fair value at December 31

468

620

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

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

^[1]

(1,248)

(2,171)

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

^[1]

(912)

(869)

^[1]

$ (224)

$ (60)

[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, 2014

Dec. 31, 2013

Defined Benefit Plan Funded Status of Plan

$ (4,590)

$ (3,547)

Unfunded plans

(3,024)

(2,567)

^[1]

(7,614)

(6,114)

Defined Benefit Plan Funded Status of Plan

(2,113)

(941)

Unfunded plans

(7,839)

(7,133)

^[1]

$ (9,952)

$ (8,074)

[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, 2014

Dec. 31, 2013

$ (25,802)

$ (20,646)

Balance at December 31

^[1]

(7,614)

(6,114)

Other assets

Current liabilities

(340)

(275)

(7,274)

(5,840)

Total recorded

(7,614)

(6,114)

6,589

4,780

Total recorded in accumulated other comprehensive income

6,616

4,840

Balance at December 31

^[1]

(9,952)

(8,074)

Other assets

302

201

Current liabilities

(325)

(358)

(9,929)

(7,917)

Total recorded

(9,952)

(8,074)

9,642

7,943

Total recorded in accumulated other comprehensive income

429

665

10,071

8,608

Balance at December 31

^[1]

(8,968)

(7,248)

Current liabilities

(369)

(359)

(8,599)

(6,889)

Total recorded

(8,968)

(7,248)

2,997

1,603

Total recorded in accumulated other comprehensive income

$ 3,048

$ 1,668

[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, 2014

Dec. 31, 2013

Dec. 31, 2012

$ 4,619

$ (7,281)

$ 1,523

Long-term rate of return on funded assets

5.00%

4.00%

5.00%

7.25%

5.75%

$ 677

$ 801

$ 665

Expected return on plan assets

807

749

820

(799)

(835)

(789)

Amortization of actuarial loss/(gain)

409

646

576

Amortization of prior service cost

Net pension enhancement and curtailment/settlement cost

276

723

333

Net periodic benefit cost

1,378

2,091

1,612

Amortization of actuarial (loss)/gain

2,494

(1,302)

1,885

(685)

(1,369)

(909)

Prior service cost/(credit)

(25)

Amortization of prior service (cost)/credit

(8)

(7)

Total recorded in net periodic benefit cost and other comprehensive income, before tax

1,776

(2,678)

969

$ 3,154

$ (587)

$ 2,581

Long-term rate of return on funded assets

4.30%

3.80%

4.00%

6.30%

6.40%

6.60%

5.40%

5.50%

5.40%

$ 590

$ 697

$ 648

Expected return on plan assets

1,138

1,076

1,145

(1,193)

(1,128)

(1,109)

Amortization of actuarial loss/(gain)

628

852

844

Amortization of prior service cost

120

117

Net pension enhancement and curtailment/settlement cost

1,540

^[1]

Net periodic benefit cost

1,283

1,636

3,185

Amortization of actuarial (loss)/gain

2,969

(1,938)

1,906

(628)

(874)

(2,384)

Prior service cost/(credit)

(70)

Amortization of prior service (cost)/credit

(120)

(117)

(688)

(155)

271

Total recorded in net periodic benefit cost and other comprehensive income, before tax

1,463

(3,054)

(253)

$ 2,746

(1,418)

$ 2,932

Pension Benefits - Non-U.S. [Member] | Japan Transaction Disposal Group [Member]

Net pension enhancement and curtailment/settlement cost

$ 1,420

Long-term rate of return on funded assets

5.00%

4.00%

5.00%

7.25%

5.75%

$ 140

$ 176

$ 134

Expected return on plan assets

383

352

380

(37)

(41)

(38)

Amortization of actuarial loss/(gain)

116

228

170

Amortization of prior service cost

Net periodic benefit cost

616

736

680

Amortization of actuarial (loss)/gain

1,518

(1,290)

1,008

(116)

(228)

(170)

Amortization of prior service (cost)/credit

(14)

(21)

(34)

(8)

(10)

Total recorded in net periodic benefit cost and other comprehensive income, before tax

1,380

(1,549)

807

$ 1,996

$ (813)

$ 1,487

[1]

Non-U.S. net pension enhancement and curtailment/settlement cost for 2012 includes $1,420 million (on a consolidated-company, before-tax basis) of accumulated other comprehensive income for the postretirement benefit reserves adjustment that was recycled into earnings and included in the Japan restructuring gain reported in “Other income”.

Pension And Other Postretirement Benefits (Summary Of The Change In Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Total (charge)/credit to other comprehensive income, before tax	$ (4,619)	$ 7,281	$ (1,523)
(Charge)/credit to income tax (see Note 4)	1,549	(2,336)	393
(Charge)/credit to investment in equity companies	(81)	49	(49)
(Charge)/credit to other comprehensive income including noncontrolling interests, after tax	(3,151)	4,994	(1,179)
Charge/(credit) to equity of noncontrolling interests	85	(279)	(124)
(Charge)/credit to other comprehensive income attributable to ExxonMobil	(3,066)	4,715	(1,303)
Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Total (charge)/credit to other comprehensive income, before tax	(1,776)	2,678	(969)
Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Total (charge)/credit to other comprehensive income, before tax	(1,463)	3,054	253
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total (charge)/credit to other comprehensive income, before tax	$ (1,380)	$ 1,549	$ (807)

Pension And Other Postretirement Benefits (Fair Value Of Benefit Plan Assets - Other Postretirement) (Details) - Other Postretirement Benefit Plans Defined Benefit [Member] - USD ($)
$ in Millions

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

U.S. Equity Securities [Member]

$ 468

$ 620

$ 581

Non-U.S. Equity Securities [Member]

106

157

Private Equity Funds [Member]

149

Corporate Debt Securities [Member]

Government Debt Securities [Member]

103

129

Asset Backed Securities [Member]

171

168

Cash [Member]

Fair Value Inputs Level2 [Member]

Fair Value Inputs Level2 [Member] | U.S. Equity Securities [Member]

466

611

Fair Value Inputs Level2 [Member] | Non-U.S. Equity Securities [Member]

^[1]

106

157

Fair Value Inputs Level2 [Member] | Corporate Debt Securities [Member]

^[1]

149

Fair Value Inputs Level2 [Member] | Government Debt Securities [Member]

^[2]

103

129

Fair Value Inputs Level2 [Member] | Asset Backed Securities [Member]

^[2]

171

168

Fair Value Inputs Level2 [Member] | Cash [Member]

^[2]

Fair Value Inputs Level3 [Member]

Fair Value Inputs Level3 [Member] | Private Equity Funds [Member]

^[3]

$ 2

$ 9

[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.

Pension And Other Postretirement Benefits (Change In The Fair Value Of Level 3 Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Pension Benefits - U.S. [Member] \| Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value at January 1	$ 523	$ 489
Net realized gains/(losses)	2	(1)
Net unrealized gains/(losses)	89	86
Net purchases/(sales)	(52)	(51)
Fair value at December 31	562	523
Pension Benefits - Non-U.S. [Member] \| Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value at January 1	502	448
Net realized gains/(losses)	23	11
Net unrealized gains/(losses)	31	57
Net purchases/(sales)	(21)	(14)
Fair value at December 31	535	502
Pension Benefits - Non-U.S. [Member] \| Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value at January 1	136	293
Net realized gains/(losses)	(17)	(13)
Net unrealized gains/(losses)	8	10
Net purchases/(sales)	(70)	(154)
Fair value at December 31	57	136
Other Postretirement Benefits [Member] \| Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value at January 1	9	7
Net unrealized gains/(losses)		3
Net purchases/(sales)	(7)	(1)
Fair value at December 31	$ 2	$ 9

Pension And Other Postretirement Benefits (Pension Plans With Accumulated Benefit Obligation In Excess Of Plan Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2014	Dec. 31, 2013
Funded Pension Plans [Member] \| Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	$ 17,505	$ 14,737
Accumulated benefit obligation	14,493	12,342
Fair value of plan assets	12,915	11,189
Funded Pension Plans [Member] \| Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	5,031	891
Accumulated benefit obligation	4,590	689
Fair value of plan assets	3,890	611
Unfunded Pension Plans [Member] \| Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	3,024	2,567
Accumulated benefit obligation	1,892	1,647
Unfunded Pension Plans [Member] \| Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	7,839	7,133
Accumulated benefit obligation	$ 6,573	$ 6,070

Pension And Other Postretirement Benefits (Estimated Amortization) (Details)
$ in Millions

12 Months Ended

Dec. 31, 2014

USD ($)

$ 1,001

^[1]

^[2]

753

^[1]

105

^[2]

211

^[1]

$ 14

^[2]

[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) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2014 USD ($)
Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefits payments expected in 2015	$ 1,628
Benefits payments expected in 2016	1,554
Benefits payments expected in 2017	1,529
Benefits payments expected in 2018	1,445
Benefits payments expected in 2019	1,410
Benefits payments expected in 2020-2024	6,714
Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions expected in 2015	560
Benefits payments expected in 2015	1,194
Benefits payments expected in 2016	1,213
Benefits payments expected in 2017	1,278
Benefits payments expected in 2018	1,298
Benefits payments expected in 2019	1,339
Benefits payments expected in 2020-2024	6,988
Gross Other Post Retirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefits payments expected in 2015	467
Benefits payments expected in 2016	479
Benefits payments expected in 2017	490
Benefits payments expected in 2018	499
Benefits payments expected in 2019	507
Benefits payments expected in 2020-2024	2,613
Other Postretirement Benefits Medicare Subsidy Receipt [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefits payments expected in 2015	24
Benefits payments expected in 2016	25
Benefits payments expected in 2017	26
Benefits payments expected in 2018	28
Benefits payments expected in 2019	29
Benefit payments expected in 2020-2024	$ 172

Disclosures About Segments And Related Information (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Disclosures About Segments And Related Information [Abstract]
Non-debt-related interest expense	$ 129	$ (123)	$ 202

Disclosures About Segments And Related Information (Schedule Of Segments And Related Information) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

$ 32,520

$ 32,580

$ 44,880

13,323

13,927

15,010

^[1],[2]

394,105

420,836

451,509

17,297

17,182

15,888

Interest revenue

117

286

327

18,015

24,263

31,045

34,256

37,741

35,179

20,017

19,619

18,530

349,493

346,808

333,795

U.S. [Member]

1,862

1,391

3,579

Non-U.S. [Member]

Upstream [Member] | U.S. [Member]

16,153

22,872

27,466

5,197

4,191

3,925

1,235

1,576

1,759

^[1]

14,826

13,712

11,039

7,723

8,343

8,764

5,139

5,170

5,104

1,300

2,197

2,025

9,098

7,480

9,697

5,089

4,975

4,020

Upstream [Member] | Non-U.S. [Member]

92,555

88,698

86,146

22,351

22,650

25,970

10,859

11,627

11,900

^[1]

22,336

25,349

27,673

38,846

45,761

47,507

8,523

8,277

7,340

15,165

21,554

25,362

19,225

26,075

21,769

10,877

9,740

9,147

Downstream [Member] | U.S. [Member]

161,033

157,465

140,848

1,618

2,199

3,575

(460)

^[1]

118,771

123,802

125,088

17,281

20,781

20,963

654

633

594

610

721

1,811

1,050

616

480

195

Downstream [Member] | Non-U.S. [Member]

18,371

19,261

18,451

1,427

1,250

9,615

387

^[1]

199,976

218,904

248,959

44,231

52,624

62,130

1,228

1,390

1,280

968

481

1,892

1,356

1,072

1,153

1,006

1,749

2,069

Chemical [Member] | U.S. [Member]

33,299

40,661

40,956

2,804

2,755

2,220

186

189

183

^[1]

15,115

15,295

14,723

10,117

11,993

12,409

370

378

376

1,032

989

755

1,564

840

338

258

217

233

Chemical [Member] | Non-U.S. [Member]

8,798

7,816

7,238

1,511

1,073

1,678

1,377

1,422

1,267

^[1]

23,063

23,753

24,003

8,098

8,232

9,750

645

632

508

(1)

358

363

232

564

272

659

3,026

3,103

3,143

Corporate And Financing [Member]

18,449

19,659

18,886

(2,388)

(1,538)

(2,103)

(445)

(449)

(492)

^[1]

274

285

258

738

702

686

Interest revenue

117

219

(63)

239

(1,418)

(2,042)

(1,032)

1,399

1,386

1,083

(308)

(227)

(277)

Segment Reporting Revenue Reconciling Item [Line Items]

$ 16,988

$ 13,248

$ 21,270

[1]	Sales and other operating revenue includes sales-based taxes of $29,342 million for 2014, $30,589 million for 2013 and $32,409 million for 2012. See Note 1, Summary of Accounting Policies.
[2]	Sales and other operating revenue includes sales-based taxes of $29,342 million for 2014, $30,589 million for 2013 and $32,409 million for 2012.

Disclosures About Segments And Related Information (Schedule Of Geographic Sales And Other Operating Revenue) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

^[1]

$ 394,105

$ 420,836

$ 451,509

Segment Reporting Revenue Reconciling Item [Line Items]

^[2]

29,342

30,589

32,409

U.S. [Member]

^[1]

148,713

152,820

150,865

Segment Reporting Revenue Reconciling Item [Line Items]

6,310

5,992

5,785

Non-U.S. [Member]

^[1]

245,392

268,016

300,644

Segment Reporting Revenue Reconciling Item [Line Items]

23,032

24,597

26,624

Canada [Member]

Segment Reporting Revenue Reconciling Item [Line Items]

^[1]

36,072

35,924

34,325

United Kingdom [Member]

Segment Reporting Revenue Reconciling Item [Line Items]

^[1]

31,346

34,061

33,600

Belgium [Member]

Segment Reporting Revenue Reconciling Item [Line Items]

^[1]

20,953

20,973

23,567

Italy [Member]

Segment Reporting Revenue Reconciling Item [Line Items]

^[1]

18,880

19,273

18,228

France [Member]

Segment Reporting Revenue Reconciling Item [Line Items]

^[1]

17,639

18,444

19,601

Singapore [Member]

Segment Reporting Revenue Reconciling Item [Line Items]

^[1]

15,407

15,623

14,606

Germany [Member]

Income, Sales-Based and Other Taxes [Line Items]

^[1]

$ 14,816

$ 15,701

$ 15,871

[1]	Sales and other operating revenue includes sales-based taxes of $29,342 million for 2014, $30,589 million for 2013 and $32,409 million for 2012. See Note 1, Summary of Accounting Policies.
[2]	Sales and other operating revenue includes sales-based taxes of $29,342 million for 2014, $30,589 million for 2013 and $32,409 million for 2012.

Disclosures About Segments And Related Information (Schedule Of Long-Lived Assets By Geographic Regions) (Details) - USD ($) $ in Millions	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Long-lived assets	$ 252,668	$ 243,650	$ 226,949
U.S. [Member]
Long-lived assets	104,000	98,271	94,336
Non-U.S. [Member]
Long-lived assets	148,668	145,379	132,613
Canada [Member]
Long-lived assets	43,858	41,522	31,979
Australia [Member]
Long-lived assets	15,328	14,258	13,415
Nigeria [Member]
Long-lived assets	12,265	12,343	12,216
Singapore [Member]
Long-lived assets	9,620	9,570	9,700
Kazakhstan [Member]
Long-lived assets	9,138	8,530	7,785
Angola [Member]
Long-lived assets	9,057	8,262	8,238
Papua New Guinea [Member]
Long-lived assets	6,099	5,768	4,599
Norway [Member]
Long-lived assets	$ 5,139	$ 6,542	$ 7,040

Income, Sales-Based And Other Taxes (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income, Sales-Based And Other Taxes [Abstract]
Net deferred income tax expense (credits)/charges for tax rate and law changes	$ (40,000,000)	$ (310,000,000)	$ 244,000,000
Reconciliation between income tax expense and theoretical U.S. tax rate, statutory rate	35.00%	35.00%	35.00%
Indefinitely reinvested, undistributed earnings from subsidiary companies outside the U.S.	$ 51,000,000,000
Potential percentage increase in unrecognized tax benefits	30.00%
Credit of net interest expense on income tax reserves		$ 207,000,000
Interest expense on income tax reserves	$ 42,000,000		$ 46,000,000
Interest payable on income tax reserves	205,000,000	156,000,000
Asset valuation allowances	2,570,000,000	$ 2,491,000,000
Valuation Allowance increase from 2013 to 2014	79,000,000
Additional net provisions [Member]
Valuation Allowance increase from 2013 to 2014	340,000,000
Effects of foreign currency translation [Member]
Valuation Allowance increase from 2013 to 2014	$ (261,000,000)

Income, Sales-Based And Other Taxes (Schedule Of Income, Sales-Based And Other Taxes) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Current

$ 16,211

$ 23,188

$ 27,441

Deferred - net

2,298

641

2,913

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

Total federal and non-U.S.

18,514

23,866

30,443

State

(499)

^[1]

397

602

Total income tax expense

18,015

24,263

31,045

^[2]

29,342

30,589

32,409

Other taxes and duties included in production and manufacturing expenses

32,286

33,230

35,558

2,633

2,500

2,550

Other taxes and duties included in SG&A expenses

596

666

749

Total other taxes and duties

35,515

36,396

38,857

Income, Sales-Based and Other Taxes [Line Items]

82,872

91,248

102,311

U.S. [Member]

Current

1,456

1,073

1,791

Deferred - net

900

(116)

1,097

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

Total federal and non-U.S.

2,361

994

2,977

State

(499)

^[1]

397

602

Total income tax expense

1,862

1,391

3,579

6,310

5,992

5,785

Other taxes and duties included in production and manufacturing expenses

378

955

1,406

1,454

1,318

1,242

Other taxes and duties included in SG&A expenses

155

150

154

Total other taxes and duties

1,987

2,423

2,802

U.S. [Member] | State Tax Adjustment [Member]

10,159

9,806

12,166

Income, Sales-Based and Other Taxes [Line Items]

Deferred tax adjustment included in State Taxes

830

Non-U.S. [Member]

Income, Sales-Based and Other Taxes [Line Items]

Current

14,755

22,115

25,650

Deferred - net

1,398

757

1,816

Total federal and non-U.S.

16,153

22,872

27,466

Total income tax expense

16,153

22,872

27,466

23,032

24,597

26,624

Other taxes and duties included in production and manufacturing expenses

31,908

32,275

34,152

1,179

1,182

1,308

Other taxes and duties included in SG&A expenses

441

516

595

Total other taxes and duties

33,528

33,973

36,055