Exxon Mobil (XOM) 10-K 24 Feb 16 2015 FY Annual report Financial data

Document And Entity Information

Document And Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2015	Jan. 31, 2016	Jun. 30, 2015
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2015
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2,015
Trading Symbol	XOM
Entity Registrant Name	EXXON MOBIL CORP
Entity Central Index Key	34,088
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		4,152,756,609
Entity Public Float			$ 346

Consolidated Statement Of Incom

Consolidated Statement Of Income - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenues and other income
Sales and other operating revenue	[1],[2]	$ 259,488	$ 394,105	$ 420,836
Income from equity affiliates		7,644	13,323	13,927
Other income		1,750	4,511	3,492
Total revenues and other income		268,882	411,939	438,255
Costs and other deductions
Crude oil and product purchases		130,003	225,972	244,156
Production and manufacturing expenses		35,587	40,859	40,525
Selling, general and administrative expenses		11,501	12,598	12,877
Depreciation and depletion		18,048	17,297	17,182
Exploration expenses, including dry holes		1,523	1,669	1,976
Interest expense		311	286	9
Sales-based taxes	[1]	22,678	29,342	30,589
Other taxes and duties		27,265	32,286	33,230
Total costs and other deductions		246,916	360,309	380,544
Income before income taxes		21,966	51,630	57,711
Income taxes		5,415	18,015	24,263
Net income including noncontrolling interests		16,551	33,615	33,448
Net income attributable to noncontrolling interests		401	1,095	868
Net income attributable to ExxonMobil		$ 16,150	$ 32,520	$ 32,580
Earnings per common share (dollars)	[3]	$ 3.85	$ 7.6	$ 7.37
Earnings per common share - assuming dilution (dollars)		$ 3.85	$ 7.6	$ 7.37
[1]	Sales and other operating revenue includes sales-based taxes of $22,678 million for 2015, $29,342 million for 2014 and $30,589 million for 2013.
[2]	Sales and other operating revenue includes sales-based taxes of $22,678 million for 2015, $29,342 million for 2014 and $30,589 million for 2013. See Note 1, Summary of Accounting Policies.
[3]	The earnings per common share and earnings per common share - assuming dilution are the same in each period shown.

Consolidated Statement Of Inco3

Consolidated Statement Of Income (Parenthetical) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Consolidated Statement Of Income [Abstract]
Sales-based taxes included in sales and other operating revenue	[1]	$ 22,678	$ 29,342	$ 30,589
[1]	Sales and other operating revenue includes sales-based taxes of $22,678 million for 2015, $29,342 million for 2014 and $30,589 million for 2013.

Consolidated Statement Of Compr

Consolidated Statement Of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Consolidated Statement Of Comprehensive Income [Abstract]
Net income including noncontrolling interests	$ 16,551	$ 33,615	$ 33,448
Other comprehensive income (net of income taxes)
Foreign exchange translation adjustment	(9,303)	(5,847)	(3,620)
Adjustment for foreign exchange translation (gain)/loss included in net income	(14)	152	(23)
Postretirement benefits reserves adjustment (excluding amortization)	2,358	(4,262)	3,174
Amortization and settlement of postretirement benefits reserves adjustment included in net periodic benefit costs	1,448	1,111	1,820
Unrealized change in fair value of stock investments	33	(63)
Realized (gain)/ loss from stock investments included in net income	27	3
Total other comprehensive income	(5,451)	(8,906)	1,351
Comprehensive income including noncontrolling interests	11,100	24,709	34,799
Comprehensive income attributable to noncontrolling interests	(496)	421	760
Comprehensive income attributable to ExxonMobil	$ 11,596	$ 24,288	$ 34,039

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Current assets
Cash and cash equivalents	$ 3,705	$ 4,616
Cash and cash equivalents - restricted		42
Notes and accounts receivable, less estimated doubtful amounts	19,875	28,009
Inventories
Crude oil, products and merchandise	12,037	12,384
Materials and supplies	4,208	4,294
Other current assets	2,798	3,565
Total current assets	42,623	52,910
Investments, advances and long-term receivables	34,245	35,239
Property, plant and equipment, at cost, less accumulated depreciation and depletion	251,605	252,668
Other assets, including intangibles, net	8,285	8,676
Total assets	336,758	349,493
Current liabilities
Notes and loans payable	18,762	17,468
Accounts payable and accrued liabilities	32,412	42,227
Income taxes payable	2,802	4,938
Total current liabilities	53,976	64,633
Long-term debt	19,925	11,653
Postretirement benefits reserves	22,647	25,802
Deferred income tax liabilities	36,818	39,230
Long-term obligations to equity companies	5,417	5,325
Other long-term obligations	21,165	21,786
Total liabilities	$ 159,948	$ 168,429
Commitments and contingencies (Note 16)
Equity
Common stock without par value (9,000 million shares authorized, 8,019 million shares issued)	$ 11,612	$ 10,792
Earnings reinvested	412,444	408,384
Accumulated other comprehensive income	(23,511)	(18,957)
Common stock held in treasury (3,863 million shares in 2015 and 3,818 million shares in 2014)	(229,734)	(225,820)
ExxonMobil share of equity	170,811	174,399
Noncontrolling interests	5,999	6,665
Total equity	176,810	181,064
Total liabilities and equity	$ 336,758	$ 349,493

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - $ / shares shares in Millions	Dec. 31, 2015	Dec. 31, 2014
Consolidated Balance Sheet [Abstract]
Common stock, without par value
Common stock, shares authorized	9,000	9,000
Common stock, shares issued	8,019	8,019
Common stock held in treasury, shares	3,863	3,818

Consolidated Statement Of Cash

Consolidated Statement Of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash flows from operating activities
Net income including noncontrolling interests	$ 16,551	$ 33,615	$ 33,448
Adjustments for noncash transactions
Depreciation and depletion	18,048	17,297	17,182
Deferred income tax charges/(credits)	(1,832)	1,540	754
Postretirement benefits expense in excess of/(less than) net payments	2,153	524	2,291
Other long-term obligation provisions in excess of/(less than) payments	(380)	1,404	(2,566)
Dividends received greater than/(less than) equity in current earnings of equity companies	(691)	(358)	3
Changes in operational working capital, excluding cash and debt
Reduction/(increase) - Notes and accounts receivable	4,692	3,118	(305)
Reduction/(increase) - Inventories	(379)	(1,343)	(1,812)
Reduction/(increase) - Other current assets	45	(68)	(105)
Increase/(reduction) - Accounts and other payables	(7,471)	(6,639)	(2,498)
Net (gain) on asset sales	(226)	(3,151)	(1,828)
All other items - net	(166)	(823)	350
Net cash provided by operating activities	30,344	45,116	44,914
Cash flows from investing activities
Additions to property, plant and equipment	(26,490)	(32,952)	(33,669)
Proceeds associated with sales of subsidiaries, property, plant and equipment, and sales and returns of investments	2,389	4,035	2,707
Decrease/(increase) in restricted cash and cash equivalents	42	227	72
Additional investments and advances	(607)	(1,631)	(4,435)
Collection of advances	842	3,346	1,124
Net cash used in investing activities	(23,824)	(26,975)	(34,201)
Cash flows from financing activities
Additions to long-term debt	8,028	5,731	345
Reductions in long-term debt	(26)	(69)	(13)
Additions to short-term debt			16
Reductions in short-term debt	(506)	(745)	(756)
Additions/(reductions) in commercial paper, and debt with three months or less maturity	1,759	2,049	12,012
Cash dividends to ExxonMobil shareholders	(12,090)	(11,568)	(10,875)
Cash dividends to noncontrolling interests	(170)	(248)	(304)
Changes in noncontrolling interests			(1)
Tax benefits related to stock-based awards	2	115	48
Common stock acquired	(4,039)	(13,183)	(15,998)
Common stock sold	5	30	50
Net cash used in financing activities	(7,037)	(17,888)	(15,476)
Effects of exchange rate changes on cash	(394)	(281)	(175)
Increase/(decrease) in cash and cash equivalents	(911)	(28)	(4,938)
Cash and cash equivalents at beginning of year	4,616	4,644	9,582
Cash and cash equivalents at end of year	$ 3,705	$ 4,616	$ 4,644

Consolidated Statement Of Chang

Consolidated Statement Of Changes In Equity - USD ($) shares in Millions, $ 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]
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
Balance (in shares) - in treasury at Dec. 31, 2012	3,517
Balance (in shares) - outstanding at Dec. 31, 2012	4,502
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)
Dispositions (in shares)	10
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
Balance (in shares) - in treasury at Dec. 31, 2013	3,684
Balance (in shares) - outstanding at Dec. 31, 2013	4,335
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)
Dispositions (in shares)	2
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
Balance (in shares) - in treasury at Dec. 31, 2014	3,818
Balance (in shares) - outstanding at Dec. 31, 2014	4,201
Amortization of stock-based awards	$ 828	828				828
Tax benefits related to stock-based awards	116	116				116
Other	(124)	(124)				(124)
Net income for the year	16,551		16,150			16,150	401
Dividends - common shares (company)			(12,090)			(12,090)
Dividends - common shares (NCI)							(170)
Dividends - common shares (total)	(12,260)
Other comprehensive income	(5,451)			(4,554)		(4,554)	(897)
Acquisitions, at cost (company)					(4,039)	(4,039)
Acquisitions, at cost (total)	(4,039)
Dispositions	$ 125				125	125
Acquisitions (in shares)	(48)
Dispositions (in shares)	3
Balance at Dec. 31, 2015	$ 176,810	$ 11,612	$ 412,444	$ (23,511)	$ (229,734)	$ 170,811	$ 5,999
Balance (in shares) - issued at Dec. 31, 2015	8,019
Balance (in shares) - in treasury at Dec. 31, 2015	3,863
Balance (in shares) - outstanding at Dec. 31, 2015	4,156

Summary Of Accounting Policies

Summary Of Accounting Policies	12 Months Ended
	Dec. 31, 2015
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 Cor poration’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 consolid ated. 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 contrac t 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 transl ation 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 reser ves, 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 pr ices 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 ow nership, 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 w orking 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 exc hanges 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). Deriv ative 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 resul ting 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 t he 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 p riority 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 tha t are directly or indirectly observable for the asse t 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. Selli ng 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, b ased 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. E xploratory well costs are carried as an asset w hen 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 c osts of productive wells and development dry holes , are c apitalized. 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 uni t-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. In the event that the unit-of-production method does not result in an equitable allocation of cost over the economic life of an upstream asset, an alternative such as the straight-line method is used. Production involves lifting the oil and gas to the surface and gathering, treating, field proce ssing 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 equip ment 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 maintenanc e 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. The Corporation performs impairment assessments whenever events o r circumstances indicate that the carrying amounts of its long-lived assets (or group of assets) may not be recoverable through future operations or disposition. Assets are grouped at the lowest level for which there are identifiable cash flows that are la rgely independent of the cash flows of other groups of assets for this assessment. Potential trigger events for impairment evaluation include: a significant decrease in the market price of a long-lived asset; a significant adverse change in the extent or manner in which an asset is being used or in its physical condition including a significant decrease in current and projected reserve volumes; a significant adverse change in legal factors or in the business cli mate that could affect the value, including an adverse action or assessment by a regulator; an accumulation of project costs significantly in excess of the amount originally expected; a current-period operating loss combined with a history and forecast of operating or cash flow losses; and a current expectation that, more likely than not, a long-lived asset will be sold or otherwise disposed of significantly before the end of its previously estimated useful life. The Corporation performs asset valuation ana lyses on an ongoing basis as a part of its asset management program. These analyses and other profitability reviews assist the Corporation in assessing whether the carrying amounts of any of its assets may not be recoverable. In general, the Corporation do es not view temporarily low prices or margins as a trigger event for conducting impairment tests. The markets for crude oil, natural gas and petroleum products, have a history of significant price volatility. Although prices will occasionally drop signific antly, industry prices over the l ong term will continue to be driven by market supply and demand. On the supply side, industry production from mature fields is declining, but this is being offset by production from new discoveries and field developments. OPEC production policies also have an impact on world oil supplies. The demand side is largely a function of global economic growth. The relative growth/decline in supply versus demand will determine industry prices over the long term, and these cannot be accurately predicted. If there were a trigger event, 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 est imates for future crude oil and natural gas commodity prices, refining and chemical margins, and foreign currency exchange rates. Volumes are based on projected field and facility production profiles, throughput, or sales. These evaluations make use of the Corporation’s price, margin, volume, and cost assumptions developed in the annual planning and budgeting process, and are consistent with the criteria management uses to evaluate investment opportunities. Where unproved reserves exist, an appropriately ri sk-adjusted amount of these reserves may be included in the evaluation. An asset group would be impaired if its undiscounted cash flows were less than the asset’s carrying value. Impairments are measured by the amount by which the carrying value exceeds fa ir value. Cash flow estimates for impairment testing exclude the effects of derivative instruments. Significant unproved properties are assessed for impairment individually, and valuation allowances against the capitalized costs are recorded based on the e stimated 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. G ains 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 n or any substantial obligation for future performance by the Corporation. Losses on prope rties 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 c apitalized 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. Capitaliz ed 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. Ove r 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 red uced 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 prim ary 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, whi ch 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 U pstream 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

Accounting Changes	12 Months Ended
	Dec. 31, 2015
Accounting Changes [Abstract]
Accounting Changes	2. Accounting Changes The Corporation did not adopt authoritative guidance in 2015 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, 2018. “Sales and Other Operating Revenue” on the Consolidated Statement of Income includes sales, excise and value-added taxes on sales transactions. When the Corporation adopts the standard, revenue will exclude sales-based taxes collected on behalf o f third parties. This change in reporting will not impact earnings. The Corporation continues to evaluate other areas of the standard and its effect on the Corporation’s financial statements.

Miscellaneous Financial Informa

Miscellaneous Financial Information	12 Months Ended
	Dec. 31, 2015
Miscellaneous Financial Information [Abstract]
Miscellaneous Financial Information	3. Miscellaneous Financial Information Research and development expenses totaled $1,008 million in 2015, $ 971 million in 201 4 and $1,0 44 million in 201 3 . Net income included before - tax aggregate foreign exchange transacti on losses of $119 million and $225 million in 2015 and 2014, respectively, and gains of $155 million in 201 3 . In 2015, 201 4 and 201 3 , net income included a loss of $186 million, and gains of $ 187 million and $ 282 million, respectively, attributable to the combined effects of LIFO i nve ntory accumulations and draw downs. The aggregate replacement cost of inventories was estimated to exceed their LIFO carrying values by $ 4.5 billion and $ 10.6 billion at December 31, 201 5 , and 201 4 , respectively . Crude oil, products and merchandise as of ye ar-end 201 5 and 201 4 consist of the following: 2015 2014 (billions of dollars) Crude oil 4.2 4.6 Petroleum products 4.1 4.1 Chemical products 2.7 2.9 Gas/other 1.0 0.8 Total 12.0 12.4

Other Comprehensive Income Info

Other Comprehensive Income Information	12 Months Ended
	Dec. 31, 2015
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, 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) Balance as of December 31, 2014 (5,952) (12,945) (60) (18,957) Current period change excluding amounts reclassified from accumulated other comprehensive income (8,204) 2,202 33 (5,969) Amounts reclassified from accumulated other comprehensive income (14) 1,402 27 1,415 Total change in accumulated other comprehensive income (8,218) 3,604 60 (4,554) Balance as of December 31, 2015 (14,170) (9,341) - (23,511) Amounts Reclassified Out of Accumulated Other Comprehensive Income - Before-tax Income/(Expense) 2015 2014 2013 (millions of dollars) Foreign exchange translation gain/(loss) included in net income (Statement of Income line: Other income) 14 (152) 23 Amortization and settlement of postretirement benefits reserves adjustment included in net periodic benefit costs (1) (2,066) (1,571) (2,616) Realized change in fair value of stock investments included in net income (Statement of Income line: Other income) (42) (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 2015 2014 2013 (millions of dollars) Foreign exchange translation adjustment 170 292 218 Postretirement benefits reserves adjustment (excluding amortization) (1,192) 2,009 (1,540) Amortization and settlement of postretirement benefits reserves adjustment included in net periodic benefit costs (618) (460) (796) Unrealized change in fair value of stock investments (17) 34 - Realized change in fair value of stock investments included in net income (15) (2) - Total (1,672) 1,873 (2,118)

Cash Flow Information

Cash Flow Information	12 Months Ended
	Dec. 31, 2015
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 2015, the “Net (gain) on asset sales” on the Consolidated S tatement of Cash Flows includes before-tax amount s from the sale of service stat ions in Europe, the sale of Up stream properties in the U.S., the sale of ExxonMobil’s interests in Chemical and Refin ing joint ventures, and the pending sale of the Torrance refinery. For 2014, the amount 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 Downstrea m 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. These net gains are reported in “Other income” on the Consolidated Statement of Income. In 2015, the “Additions /( reductions) in commercial paper, and debt with three months or less maturity” on the Consolidated Statement o f Cash Flows includes a net $358 million addition of commercial paper with maturity over three months . The gross amount issued was $8.1 billion, while the gross amount repaid was $7.7 billion. In 2015, ExxonMobil completed an asset exchange that resulted in v alue received of approximately $500 million including $100 million in cash. The non-cash portion was not included in the “Sales of subsidiaries, investments, and property, plant and equipment” or the “All other items-net” lines on the Statement of Cash Flo ws. Capital leases of approximately $1 billion were not included in the “Additions to long-term debt” or “Additions to property, plant and equipment” lines on the Statement of Cash Flows. In 2014, ExxonMobil completed asset exchanges, primarily non-cash tr ansactions, 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 . 2015 2014 2013 (millions of dollars) Cash payments for interest 586 380 426 Cash payments for income taxes 7,269 18,085 25,066

Additional Working Capital Info

Additional Working Capital Information	12 Months Ended
	Dec. 31, 2015
Additional Working Capital Information [Abstract]
Additional Working Capital Information	6 . Additional Working Capital Information Dec. 31 Dec. 31 2015 2014 (millions of dollars) Notes and accounts receivable Trade, less reserves of $107 million and $113 million 13,243 18,541 Other, less reserves of $4 million and $48 million 6,632 9,468 Total 19,875 28,009 Notes and loans payable Bank loans 231 473 Commercial paper 17,973 16,225 Long-term debt due within one year 558 770 Total 18,762 17,468 Accounts payable and accrued liabilities Trade payables 18,074 25,286 Payables to equity companies 4,639 6,589 Accrued taxes other than income taxes 2,937 3,290 Other 6,762 7,062 Total 32,412 42,227 The Corporation has short-term committed lines of credit of $6.0 billion which were unused as of December 31, 2015. T hese lines are available for general corporate purposes . The weighted-average interest rate on short-term borrowings outstanding was 0.4 percent and 0 . 3 percent at December 31, 201 5 , and 201 4 , respectively.

Equity Company Information

Equity Company Information	12 Months Ended
	Dec. 31, 2015
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, and natural gas marketing in North America; natural gas exploration, production and distribution , and downstream operations in Europe; and e xploration , 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 to tal equity company revenues from sales to ExxonMobil consolidated companies was 15 percent, 1 4 percent and 1 3 percent in the years 201 5 , 201 4 and 20 13 , respectively. In 2013 and 2014, the Corporation and Rosneft established various entities to conduct expl or ation 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 e quity share in these entities. These joint ventures are conside red V ariable 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 Ru ssian en ergy sector. With respect to the foregoing, each joint venture continues to comply with all applicable laws, rules and regulations. The Corporation's maximum before-tax exposure to loss from these joint ventures as of December 31, 2015, is $1.0 billion . 2015 2014 2013 Equity Company ExxonMobil ExxonMobil ExxonMobil Financial Summary Total Share Total Share Total Share (millions of dollars) Total revenues 111,866 34,297 183,708 55,855 236,161 68,084 Income before income taxes 36,379 10,670 65,549 19,014 69,454 19,999 Income taxes 11,048 3,019 20,520 5,684 21,618 6,069 Income from equity affiliates 25,331 7,651 45,029 13,330 47,836 13,930 Current assets 32,879 11,244 49,905 16,802 62,398 19,545 Long-term assets 109,684 32,878 110,754 33,619 116,450 35,695 Total assets 142,563 44,122 160,659 50,421 178,848 55,240 Current liabilities 22,947 6,738 37,333 11,472 54,550 15,243 Long-term liabilities 60,388 17,165 66,231 19,470 68,857 20,873 Net assets 59,228 20,219 57,095 19,479 55,441 19,124 A list of significant equity companies as of December 31, 201 5 , 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 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 Italia s.r.l. 50 Infineum USA L.P. 50 Saudi Yanbu Petrochemical Co. 50

Investments, Advances And Long-

Investments, Advances And Long-Term Receivables	12 Months Ended
	Dec. 31, 2015
Investments, Advances And Long-Term Receivables [Abstract]
Investments, Advances And Long-Term Receivables	8 . Investments, Advances and Long-Term Recei vables Dec. 31, Dec. 31, 2015 2014 (millions of dollars) Companies carried at equity in underlying assets Investments 20,337 20,017 Advances 9,110 9,818 Total equity company investments and advances 29,447 29,835 Companies carried at cost or less and stock investments carried at fair value 274 526 Long-term receivables and miscellaneous investments at cost or less, net of reserves of $3,040 million and $2,662 million 4,524 4,878 Total 34,245 35,239

Property, Plant And Equipment A

Property, Plant And Equipment And Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2015
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, 2015 December 31, 2014 Property, Plant and Equipment Cost Net Cost Net (millions of dollars) Upstream 347,821 203,822 347,170 205,308 Downstream 50,742 21,330 53,327 22,639 Chemical 32,481 16,247 30,717 14,918 Other 16,293 10,206 15,575 9,803 Total 447,337 251,605 446,789 252,668 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. The Corpora tion periodically reviews the estimated asset service life of its property, plant and equipment. Effective January 1, 2016, the Corporation revised the estimated asset service life of its investments in process equipment in the Chemical s egment to 25 years . This revision will not have a material impact on the Corporation’s financial statements. Accumulated depr eciation and depletion totaled $195,732 million at the end of 201 5 and $ 194 , 121 million at the end of 201 4 . Interest capitalized in 201 5 , 201 4 and 20 13 was $ 482 million, $344 million and $309 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, t he Corporation uses assumpti ons 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; dis count rates; and inflation rates. Asset retirement obligations incurred in the current period wer e Level 3 fair value measurements. The costs associated with these liabilities are capitalized as part of the related assets and depreciated as the reserves ar e 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: 2015 2014 (millions of dollars) Beginning balance 13,424 12,988 Accretion expense and other provisions 775 871 Reduction due to property sales (208) (151) Payments made (928) (724) Liabilities incurred 283 122 Foreign currency translation (931) (908) Revisions 1,289 1,226 Ending balance 13,704 13,424

Accounting For Suspended Explor

Accounting For Suspended Exploratory Well Costs	12 Months Ended
	Dec. 31, 2015
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 oper ating 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: 2015 2014 2013 (millions of dollars) Balance beginning at January 1 3,587 2,707 2,679 Additions pending the determination of proved reserves 847 1,095 293 Charged to expense (5) (28) (52) Reclassifications to wells, facilities and equipment based on the determination of proved reserves (43) (160) (107) Divestments/Other (14) (27) (106) Ending balance at December 31 4,372 3,587 2,707 Ending balance attributed to equity companies included above 696 645 13 Period end capitalized suspended exploratory well costs: 2015 2014 2013 (millions of dollars) Capitalized for a period of one year or less 847 1,095 293 Capitalized for a period of between one and five years 2,386 1,659 1,705 Capitalized for a period of between five and ten years 826 544 470 Capitalized for a period of greater than ten years 313 289 239 Capitalized for a period greater than one year - subtotal 3,525 2,492 2,414 Total 4,372 3,587 2,707 Exploration activity often involves drilling multiple wells, over a number of years, to fully evaluate a project. The table below provides a breakdown of t he 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, which includes the Rosneft joint venture exploration activity (refer to the relevant portion of Note 7). 2015 2014 2013 Number of projects with first capitalized well drilled in the preceding 12 months 4 8 8 Number of projects that have exploratory well costs capitalized for a period of greater than 12 months 55 53 50 Total 59 61 58 Of the 55 projects that have exploratory well costs capitalized for a period greater than 12 months as of December 31, 2015, 18 projects have drilling in the preceding 12 months or exploratory activity either planned in the next two years or subject to sanctions. The remaining 37 projects are those with completed exploratory activity progressing toward development. The table below provides additional detail for those 37 projects, which total $1,15 4 million. Years Dec. 31, Wells Country/Project 2015 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 7 2001 Gas field near Kipper/Tuna development, awaiting capacity in existing/planned infrastructure. - SE Longtom 11 2010 Gas field near Tuna development, awaiting capacity in existing/planned infrastructure. - SE Remora 34 2010 Gas field near Marlin development, awaiting capacity in existing/planned infrastructure. Canada - Horn River 241 2009 - 2012 Evaluating development alternatives to tie into planned infrastructure. Indonesia - Alas Tua West 16 2010 Evaluating development plan to tie into planned production facilities. - Cepu Gas 29 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. - Kalamkas 18 2006 - 2009 Evaluating development alternatives, while continuing discussions with the government regarding development plan. Malaysia - 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. - 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 13 2008 - 2009 Evaluating development plan for tieback to existing production facilities. - Lavrans 15 1995 - 1999 Evaluating development plan, awaiting capacity in existing Kristin production facility. - Other (7 projects) 25 2008 - 2014 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. 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 2015 (37 projects) 1,154

Leased Facilities

Leased Facilities	12 Months Ended
	Dec. 31, 2015
Leased Facilities [Abstract]
Leased Facilities	11. Leased Facilities At December 31, 2015 , 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 $ 4,877 million as indicated in the table. Estimated related rental income from noncancelable sub leases is $ 32 million. Lease Payments Under Minimum Commitments Related Drilling Rigs Sublease and Related Rental Equipment Other Total Income (millions of dollars) 2016 827 826 1,653 7 2017 408 595 1,003 6 2018 134 421 555 2 2019 89 255 344 2 2020 77 188 265 2 2021 and beyond 86 971 1,057 13 Total 1,621 3,256 4,877 32 Net rental cost under both cancelable and noncancelable operating leases incurred during 2015 , 2014 and 2013 were as follows : 2015 2014 2013 (millions of dollars) Rental cost Drilling rigs and related equipment 1,853 1,763 1,424 Other 2,120 2,314 2,417 Total 3,973 4,077 3,841 Less sublease rental income 44 52 44 Net rental cost 3,929 4,025 3,797

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Share	1 2 . Earnings Per Share 2015 2014 2013 Earnings per common share Net income attributable to ExxonMobil (millions of dollars) 16,150 32,520 32,580 Weighted average number of common shares outstanding (millions of shares) 4,196 4,282 4,419 Earnings per common share (dollars) (1) 3.85 7.60 7.37 Dividends paid per common share (dollars) 2.88 2.70 2.46 (1) The earnings per common share and earnings per common share - assuming dilution are the same in each period shown .

Financial Instruments And Deriv

Financial Instruments And Derivatives	12 Months Ended
	Dec. 31, 2015
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 notab le is long-term debt. The estimated fair value of total long-term debt, excluding capital ized lease obligations, was $ 18.9 billion and $ 11.7 billion at December 31, 201 5 , and 201 4 , respectively, as compared to recorded book values of $ 18.7 billion and $ 11.3 billion at December 31, 2015, and 2014 , respectively. The increase in the estimated fair value and book value of long-term debt reflects the Corporation’s issuance of $8.0 b illion of long-term debt in the fir st quarter of 2015 . The fair value of long-term debt by hierarchy level at Decem ber 31, 2015 , is: Level 1 $18,584 million; Level 2 $208 million; and Level 3 $62 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, liabilitie s and forecasted transactions. The estimated fair value of derivative instruments outstanding and recorded on the balance sheet was a net asset of $ 21 million at year-end 201 5 and a net asset of $ 75 million at year-end 201 4 . Assets and liabilities associ ated 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 recogn ized a before-tax gain or (loss) related to derivative instruments of $ 39 million, $ 110 million and $ (7) million during 201 5 , 201 4 and 20 13 , 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

Long-Term Debt	12 Months Ended
	Dec. 31, 2015
Long-Term Debt [Abstract]
Long-Term Debt	14. Long-Term Debt At December 31, 201 5 , long-term debt consisted of $19,217 million due in U.S. dollars and $708 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 $558 million, which matures within one year and is included in current liabilities. The increase in the book value of long-term debt reflects the Corp oration’s issuance of $8.0 billi on of long-term d ebt in the first quarter of 2015 . The amounts of long-term deb t, including capitalized lease obligations, maturing in each of the four years after December 31, 201 6 , in millions of dollars, are: 201 7 – $2,959 ; 201 8 – $2,967 ; 201 9 – $2,374 ; and 2020 – $1,602 . At December 31, 2015, the Corporation’s unused long-term credit lines were $0.4 billion. Summarized long-term debt at year-e nd 201 5 and 20 14 are shown in the table below: 2015 2014 (millions of dollars) Exxon Mobil Corporation 0.921% notes due 2017 1,500 1,500 Floating-rate notes due 2017 (1) 750 750 Floating-rate notes due 2018 (2) 500 - 1.305% notes due 2018 1,600 - 1.819% notes due 2019 1,750 1,750 Floating-rate notes due 2019 (3) 500 500 1.912% notes due 2020 1,500 - 2.397% notes due 2022 1,150 - Floating-rate notes due 2022 (4) 500 - 3.176% notes due 2024 1,000 1,000 2.709% notes due 2025 1,750 - 3.567% notes due 2045 1,000 - XTO Energy Inc. (5) 5.650% senior notes due 2016 - 207 6.250% senior notes due 2017 465 477 5.500% senior notes due 2018 377 383 6.500% senior notes due 2018 463 474 6.100% senior notes due 2036 198 199 6.750% senior notes due 2037 307 309 6.375% senior notes due 2038 235 236 Mobil Producing Nigeria Unlimited (6) Variable notes due 2016-2019 101 399 Esso (Thailand) Public Company Ltd. (7) Variable notes due 2016-2020 83 121 Mobil Corporation 8.625% debentures due 2021 249 249 Industrial revenue bonds due 2017-2051 (8) 2,611 2,611 Other U.S. dollar obligations (9) 97 104 Other foreign currency obligations 1 9 Capitalized lease obligations (10) 1,238 375 Total long-term debt 19,925 11,653 (1) Average effect ive interest rate of 0.3% in 2015 and 0.3% in 2014. (2) Average effecti ve interest rate of 0.4% in 2015 . (3 ) Average effective inter est rate of 0.5% in 2015 and 0.4 % in 2014. (4 ) Averag e effective interest rate of 0.7 % in 2015. (5) Includes premiums of $ 179 million in 2015 and $219 million in 2014 . (6) Average effective interest rate of 4.6 % in 201 5 and 4.5% in 2014 . (7) Average effective interest rate of 2.1 % in 201 5 and 2.4% in 2014 . (8) Average effective interest rate of 0.02 % i n 201 5 and 0.03% in 2014 . (9) Average effective interest rate of 3.8 % in 201 5 and 4.2% in 2014. (10) Average imputed interest rate of 9.2% in 2015 and 7.0 % in 201 4 .

Incentive Program

Incentive Program	12 Months Ended
	Dec. 31, 2015
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 maximu m 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 201 5 , remaining shares available for award under the 2003 Incentive Program were 10 0 million . Restricted Stock and Restricted Stock Units . Awards totaling 9,681 thousand, 9,775 thousand , and 9,729 thousand of restricted ( nonvested ) common stock units were granted in 201 5 , 201 4 and 20 13 , respectively. Compensation expens e 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. S hares for these awards are issued to employees from treasury stock. The units that are settled in cash are recorded a s 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 vestin g 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 th e 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, 201 5 . 2015 Weighted Average Grant-Date Restricted stock and units outstanding Shares Fair Value per Share (thousands) (dollars) Issued and outstanding at January 1 44,439 81.45 2014 award issued in 2015 9,758 95.20 Vested (9,945) 79.86 Forfeited (189) 82.26 Issued and outstanding at December 31 44,063 84.85 Value of restricted stock and units 2015 2014 2013 Grant price (dollars) 81.27 95.20 94.47 Value at date of grant: (millions of dollars) Restricted stock and units settled in stock 727 858 843 Units settled in cash 60 73 76 Total value 787 931 919 As of December 31, 201 5 , there was $ 2, 222 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 $ 8 55 million, $ 8 31 million and $ 854 million for 201 5 , 201 4 and 201 3 , respectively. The income tax benefit recognized in income related to this compensation expense was $ 78 million, $ 7 6 million and $ 7 8 million for the same periods, respectively. The fair value of shares and units vested in 201 5 , 201 4 and 20 1 3 was $ 808 million, $ 946 million and $ 1,040 million, respectively. Cash p ayments of $64 million, $ 73 million and $ 6 7 million for vested restr icted stock units settled in cash were made in 201 5 , 201 4 a nd 20 13 , respectively.

Litigation And Other Contingenc

Litigation And Other Contingencies	12 Months Ended
	Dec. 31, 2015
Litigation And Other Contingencies [Abstract]
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 re asonably 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 signif icant, 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 sh ould 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 Exxon Mobil 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 Decemb er 31, 2015 , for guarantees relating to notes, loans and performance under contracts. Where guarantees for environmental remediation and other similar matter s do not include a stated cap , the amounts reflect management’s estimate of the maximum potentia l exposure. Dec. 31, 2015 Equity Company Other Third-Party Obligations (1) Obligations Total (millions of dollars) Guarantees Debt-related 98 35 133 Other 2,539 4,553 7,092 Total 2,637 4,588 7,225 (1) ExxonMobil share. 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 co nsequences 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 t hird parties have used to secure financing for the facilities that will provide the contracted goods or services. Payments Due by Period 2017- 2021 and 2016 2020 Beyond Total (millions of dollars) Unconditional purchase obligations (1) 133 493 310 936 (1) Undiscounted obligations of $936 million mainly pertain to pipeline throughput agreements and include $411 million of obligations to equity companies. The present value of these commitments, which excludes imputed interest of $144 million, totaled $792 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 o wned 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 re fused 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). 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 fu ll. 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., agai nst PdVSA and a PdVSA affiliate, PdVSA CN, in an arbitration under the rules of the International Chamber of Commerce. On June 12, 2015, the Tribunal rejected in its entirety Venezuela’s October 23, 2014, application to revise the ICSID award. The Tribuna l also lifted the associated stay of enforcement that had been entered upon the filing of the application to revise. Still pending is Venezuela’s February 2, 2015, application to ICSID seeking annulment of the ICSID award. That application alleges that, i n 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. A separate stay of the ICSID award was entered following the filing of the annulment application. On July 7, 2015, the ICSID Committee considering the annulment application heard arguments from the parties on whether to lift the stay of the award associated with that application. On July 28, 2015, the Committee issued an order that would lift the stay of enforcement unless, within 30 days, Venezuela delivered a commitment to pay the award if the application to annul is denied. On September 17, 2015, the Committee ruled that Venezuela had complied with the requirement to submit a written co mmitment to pay the award and so left the stay of enforcement in place. A hearing on Venezuela’s application for annulment, previously scheduled for January 25-27, 2016, has been rescheduled for March 8-9, 2016. The United States District Court for the S outhern District of New York entered judgment on the ICSID award on October 10, 2014. Motions filed by Venezuela to vacate that judgment on procedural grounds and to modify the judgment by reducing the rate of interest to be paid on the ICSID award from th e entry of the court’s judgment, until the date of payment, were denied on February 13, 2015, and March 4, 2015, respectively. On March 9, 2015, Venezuela filed a notice of appeal of the court’s actions on the two motions. Oral arguments on this appeal wer e held before the United States Court of Appeals for the Second Circuit on January 7, 2016. The District Court’s judgment on the ICSID award is currently stayed until such time as ICSID’s stay of the award entered following Venezuela’s filing of its applic ation to annul has 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. Ex xonMobil'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 th e 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 resp ects 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 h ave the award set aside. On May 22, 2012, the court set aside the award. The Contractors appealed that judgment to the Court of Appeal, Abuja Judicial Division. In June 2013, the Contractors filed a lawsuit against NNPC in the Nigerian federal high court i n 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 awa rd against NNPC assets residing within that jurisdiction. NNPC has moved to dismiss the lawsuit. Proceedings in the Southern District of New York are currently stayed. 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 Postretiremen

Pension And Other Postretirement Benefits	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2015 2014 2015 2014 (percent) Weighted-average assumptions used to determine benefit obligations at December 31 Discount rate 4.25 4.00 3.60 3.10 4.25 4.00 Long-term rate of compensation increase 5.75 5.75 4.80 5.30 5.75 5.75 (millions of dollars) Change in benefit obligation Benefit obligation at January 1 20,529 17,304 30,047 27,357 9,436 7,868 Service cost 864 677 689 590 170 140 Interest cost 785 807 850 1,138 346 383 Actuarial loss/(gain) (545) 3,192 (1,517) 4,929 (617) 1,522 Benefits paid (1) (2) (2,050) (1,427) (1,287) (1,366) (482) (525) Foreign exchange rate changes - - (3,242) (2,540) (106) (48) Amendments, divestments and other - (24) (423) (61) (465) 96 Benefit obligation at December 31 19,583 20,529 25,117 30,047 8,282 9,436 Accumulated benefit obligation at December 31 15,666 16,385 22,362 26,318 - - (1) Benefit payments for funded and unfunded plans. (2) For 201 5 and 201 4 , other postretirement benefits paid are net of $15 million and $ 21 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 2017 and subsequent years . A one-percentage-point increase in the health care cost trend rate would increase service and interest cost by $ 88 million and the postretirement benefit obligation by $ 963 million. A one-percentage-point decrease in the health care cost trend rate would decrease service and interest c ost by $ 66 million and the postretirement benefit obligation by $ 764 million. Pension Benefits Other Postretirement U.S. Non-U.S. Benefits 2015 2014 2015 2014 2015 2014 (millions of dollars) Change in plan assets Fair value at January 1 12,915 11,190 20,095 19,283 468 620 Actual return on plan assets (307) 1,497 918 3,153 - 41 Foreign exchange rate changes - - (2,109) (1,738) - - Company contribution - 1,476 515 554 42 31 Benefits paid (1) (1,623) (1,248) (890) (912) (96) (224) Other - - (112) (245) - - Fair value at December 31 10,985 12,915 18,417 20,095 414 468 (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. 2015 2014 2015 2014 (millions of dollars) Assets in excess of/(less than) benefit obligation Balance at December 31 Funded plans (5,782) (4,590) (588) (2,113) Unfunded plans (2,816) (3,024) (6,112) (7,839) Total (8,598) (7,614) (6,700) (9,952) 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 2015 2014 2015 2014 2015 2014 (millions of dollars) Assets in excess of/(less than) benefit obligation Balance at December 31 (1) (8,598) (7,614) (6,700) (9,952) (7,868) (8,968) Amounts recorded in the consolidated balance sheet consist of: Other assets - - 454 302 - - Current liabilities (311) (340) (299) (325) (363) (369) Postretirement benefits reserves (8,287) (7,274) (6,855) (9,929) (7,505) (8,599) Total recorded (8,598) (7,614) (6,700) (9,952) (7,868) (8,968) Amounts recorded in accumulated other comprehensive income consist of: Net actuarial loss/(gain) 6,138 6,589 6,413 9,642 2,171 2,997 Prior service cost 21 27 (83) 429 (460) 51 Total recorded in accumulated other comprehensive income 6,159 6,616 6,330 10,071 1,711 3,048 (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 percentage s and the long-term return assumption for each asset class . Other Pension Benefits Postretirement U.S. Non-U.S. Benefits 2015 2014 2013 2015 2014 2013 2015 2014 2013 Weighted-average assumptions used to determine net periodic benefit cost for years ended December 31 (percent) Discount rate 4.00 5.00 4.00 3.10 4.30 3.80 4.00 5.00 4.00 Long-term rate of return on funded assets 7.00 7.25 7.25 5.90 6.30 6.40 7.00 7.25 7.25 Long-term rate of compensation increase 5.75 5.75 5.75 5.30 5.40 5.50 5.75 5.75 5.75 Components of net periodic benefit cost (millions of dollars) Service cost 864 677 801 689 590 697 170 140 176 Interest cost 785 807 749 850 1,138 1,076 346 383 352 Expected return on plan assets (830) (799) (835) (1,094) (1,193) (1,128) (28) (37) (41) Amortization of actuarial loss/(gain) 544 409 646 730 628 852 206 116 228 Amortization of prior service cost 6 8 7 87 120 117 (24) 14 21 Net pension enhancement and curtailment/settlement cost 499 276 723 22 - 22 - - - Net periodic benefit cost 1,868 1,378 2,091 1,284 1,283 1,636 670 616 736 Changes in amounts recorded in accumulated other comprehensive income: Net actuarial loss/(gain) 592 2,494 (1,302) (1,375) 2,969 (1,938) (589) 1,518 (1,290) Amortization of actuarial (loss)/gain (1,043) (685) (1,369) (752) (628) (874) (206) (116) (228) Prior service cost/(credit) - (25) - (401) (70) 30 (535) - - Amortization of prior service (cost)/credit (6) (8) (7) (87) (120) (117) 24 (14) (21) Foreign exchange rate changes - - - (1,126) (688) (155) (31) (8) (10) Total recorded in other comprehensive income (457) 1,776 (2,678) (3,741) 1,463 (3,054) (1,337) 1,380 (1,549) Total recorded in net periodic benefit cost and other comprehensive income, before tax 1,411 3,154 (587) (2,457) 2,746 (1,418) (667) 1,996 (813) Costs for defined contribution plans were $ 405 million, $ 393 million and $ 39 2 million in 201 5 , 201 4 and 2 0 13 , respectively. A summary of the change in accumulated other comprehensive income is shown in the table below: Total Pension and Other Postretirement Benefits 2015 2014 2013 (millions of dollars) (Charge)/credit to other comprehensive income, before tax U.S. pension 457 (1,776) 2,678 Non-U.S. pension 3,741 (1,463) 3,054 Other postretirement benefits 1,337 (1,380) 1,549 Total (charge)/credit to other comprehensive income, before tax 5,535 (4,619) 7,281 (Charge)/credit to income tax (see Note 4) (1,810) 1,549 (2,336) (Charge)/credit to investment in equity companies 81 (81) 49 (Charge)/credit to other comprehensive income including noncontrolling interests, after tax 3,806 (3,151) 4,994 Charge/(credit) to equity of noncontrolling interests (202) 85 (279) (Charge)/credit to other comprehensive income attributable to ExxonMobil 3,604 (3,066) 4,715 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 inves ted 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 the major non-U.S. plans 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, respect ively. 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 2015 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, 2015, Using: at December 31, 2015, Using: Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions of dollars) Asset category: Equity securities U.S. - 1,992 (1) - 1,992 - 3,179 (1) - 3,179 Non-U.S. - 1,775 (1) - 1,775 179 (2) 3,429 (1) - 3,608 Private equity - - 595 (3) 595 - - 581 (3) 581 Debt securities Corporate - 4,161 (4) - 4,161 - 2,561 (4) - 2,561 Government - 2,394 (4) - 2,394 243 (5) 8,125 (4) - 8,368 Asset-backed - 3 (4) - 3 - 71 (4) - 71 Real estate funds - - - - - - - - Cash - 50 (6) - 50 11 12 (7) - 23 Total at fair value - 10,375 595 10,970 433 17,377 581 18,391 Insurance contracts at contract value 15 26 Total plan assets 10,985 18,417 ( 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 excha nges, 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 gove rnment debt securities that are traded on active exchanges, fair value is based on observable quoted prices. (6 ) 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. (7 ) 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, 2015, Using: Level 1 Level 2 Level 3 Total (millions of dollars) Asset category: Equity securities U.S. - 96 (1) - 96 Non-U.S. - 67 (1) - 67 Private equity - - - - Debt securities Corporate - 79 (2) - 79 Government - 170 (2) - 170 Asset-backed - 1 (2) - 1 Cash - 1 - 1 Total at fair value - 414 - 414 (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 ac tive excha nges, 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. The change in the fair value in 2015 of Level 3 assets that use significant unobservable inputs to measure fair value is shown in the table below: 2015 Pension Other U.S. Non-U.S. Postretirement Private Private Real Private Equity Equity Estate Equity (millions of dollars) Fair value at January 1 562 535 57 2 Net realized gains/(losses) 1 26 (5) - Net unrealized gains/(losses) 106 64 - - Net purchases/(sales) (74) (44) (52) (2) Fair value at December 31 595 581 - - 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: 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: 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 (1) For U.S. and non-U.S. equity securities held in the form of fund units that are redeemable at the measurement date, the unit value is treated as a Level 2 input. The fair value of the securities owned by the funds is based on observable quoted prices on active exchanges, which are Level 1 inputs. (2) For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings. (3) For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions. 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 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. 2015 2014 2015 2014 (millions of dollars) For funded pension plans with an accumulated benefit obligation in excess of plan assets: Projected benefit obligation 16,767 17,505 1,827 5,031 Accumulated benefit obligation 13,913 14,493 1,373 4,590 Fair value of plan assets 10,985 12,915 1,299 3,890 For unfunded pension plans: Projected benefit obligation 2,816 3,024 6,112 7,839 Accumulated benefit obligation 1,753 1,892 5,290 6,573 Other Pension Benefits Postretirement U.S. Non-U.S. Benefits (millions of dollars) Estimated 2016 amortization from accumulated other comprehensive income: Net actuarial loss/(gain) (1) 930 543 152 Prior service cost (2) 6 55 (30) (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 2016 2,000 525 - - Benefit payments expected in: 2016 1,548 1,145 457 24 2017 1,491 1,128 470 25 2018 1,411 1,178 481 26 2019 1,382 1,193 490 28 2020 1,342 1,227 497 29 2021 - 2025 6,594 6,359 2,518 170

Disclosures About Segments And

Disclosures About Segments And Related Information	12 Months Ended
	Dec. 31, 2015
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 produc ts. 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 Corporat ion 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 abou t 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, intere st revenue relates to interest earned on cash deposits and marketable securities. Interest expense includes non-debt-related interest expense of $100 million and $ 129 million in 2015 and 20 14 , 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, 2015 Earnings after income tax (1,079) 8,180 1,901 4,656 2,386 2,032 (1,926) 16,150 Earnings of equity companies included above 226 5,831 170 444 144 1,235 (406) 7,644 Sales and other operating revenue (1) 8,241 15,812 73,063 134,230 10,880 17,254 8 259,488 Intersegment revenue 4,344 20,839 12,440 22,166 7,442 5,168 274 - Depreciation and depletion expense 5,301 9,227 664 1,003 375 654 824 18,048 Interest revenue - - - - - - 46 46 Interest expense 26 27 8 4 - 1 245 311 Income taxes (879) 4,703 866 1,325 646 633 (1,879) 5,415 Additions to property, plant and equipment 6,915 14,561 916 1,477 1,865 629 1,112 27,475 Investments in equity companies 5,160 10,980 95 1,179 125 3,025 (227) 20,337 Total assets 93,648 155,316 16,498 29,808 10,174 18,236 13,078 336,758 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 (1) Sales and other operating revenue includes sales-based taxes of $22,678 million for 2015, $29,342 million for 2014 and $30 , 589 million for 201 3 . See Note 1, Summary of Accounting Policies. Geographic Sales and other operating revenue (1) 2015 2014 2013 (millions of dollars) United States 92,184 148,713 152,820 Non-U.S. 167,304 245,392 268,016 Total 259,488 394,105 420,836 Significant non-U.S. revenue sources include: United Kingdom 23,651 31,346 34,061 Canada 22,876 36,072 35,924 Italy 13,795 18,880 19,273 Belgium 13,154 20,953 20,973 France 11,808 17,639 18,444 Singapore 10,790 15,407 15,623 Germany 10,045 14,816 15,701 (1) Sales and other operating revenue includes sales-based taxes of $22,678 million for 2015, $29,342 million for 2014 and $30,589 million for 2013. See Note 1, Summary of Accounting Policies. Long-lived assets 2015 2014 2013 (millions of dollars) United States 107,039 104,000 98,271 Non-U.S. 144,566 148,668 145,379 Total 251,605 252,668 243,650 Significant non-U.S. long-lived assets include: Canada 39,775 43,858 41,522 Australia 15,894 15,328 14,258 Nigeria 12,222 12,265 12,343 Kazakhstan 9,705 9,138 8,530 Singapore 9,681 9,620 9,570 Angola 8,777 9,057 8,262 Papua New Guinea 5,985 6,099 5,768

Income, Sales-Based And Other T

Income, Sales-Based And Other Taxes	12 Months Ended
	Dec. 31, 2015
Income, Sales-Based And Other Taxes [Abstract]
Income, Sales-Based And Other Taxes	1 9 . Income, Sale s-Based and Other Taxes 2015 2014 2013 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 - 7,126 7,126 1,456 14,755 16,211 1,073 22,115 23,188 Deferred - net (1,166) (571) (1,737) 900 1,398 2,298 (116) 757 641 U.S. tax on non-U.S. operations 38 - 38 5 - 5 37 - 37 Total federal and non-U.S. (1,128) 6,555 5,427 2,361 16,153 18,514 994 22,872 23,866 State (1) (12) - (12) (499) - (499) 397 - 397 Total income tax expense (1,140) 6,555 5,415 1,862 16,153 18,015 1,391 22,872 24,263 Sales-based taxes 6,402 16,276 22,678 6,310 23,032 29,342 5,992 24,597 30,589 All other taxes and duties Other taxes and duties 162 27,103 27,265 378 31,908 32,286 955 32,275 33,230 Included in production and manufacturing expenses 1,157 828 1,985 1,454 1,179 2,633 1,318 1,182 2,500 Included in SG&A expenses 150 390 540 155 441 596 150 516 666 Total other taxes and duties 1,469 28,321 29,790 1,987 33,528 35,515 2,423 33,973 36,396 Total 6,731 51,152 57,883 10,159 72,713 82,872 9,806 81,442 91,248 (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 abov e provisions for d eferred income taxes include a net charge of $177 million in 2015 and net credits of $40 million in 2014 and $310 million in 2013 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 2015 , 2014 and 2013 is as follows: 2015 2014 2013 (millions of dollars) Income before income taxes United States 147 9,080 9,746 Non-U.S. 21,819 42,550 47,965 Total 21,966 51,630 57,711 Theoretical tax 7,688 18,071 20,199 Effect of equity method of accounting (2,675) (4,663) (4,874) Non-U.S. taxes in excess of theoretical U.S. tax 1,415 5,442 10,528 U.S. tax on non-U.S. operations 38 5 37 State taxes, net of federal tax benefit (8) (324) 258 Other (1,043) (516) (1,885) Total income tax expense 5,415 18,015 24,263 Effective tax rate calculation Income taxes 5,415 18,015 24,263 ExxonMobil share of equity company income taxes 3,011 5,678 6,061 Total income taxes 8,426 23,693 30,324 Net income including noncontrolling interests 16,551 33,615 33,448 Total income before taxes 24,977 57,308 63,772 Effective income tax rate 34% 41% 48% 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: 2015 2014 (millions of dollars) Property, plant and equipment 49,409 51,643 Other liabilities 4,613 4,359 Total deferred tax liabilities 54,022 56,002 Pension and other postretirement benefits (6,286) (8,140) Asset retirement obligations (6,277) (6,162) Tax loss carryforwards (4,983) (4,099) Other assets (5,592) (6,446) Total deferred tax assets (23,138) (24,847) Asset valuation allowances 1,730 2,570 Net deferred tax liabilities 32,614 33,725 In 2015, asset valuation allowances of $1,73 0 million decreased by $840 million and included net provisions of $681 million and effects of foreign currency translation of $159 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 2015 2014 (millions of dollars) Other current assets (1,329) (2,001) Other assets, including intangibles, net (3,421) (3,955) Accounts payable and accrued liabilities 546 451 Deferred income tax liabilities 36,818 39,230 Net deferred tax liabilities 32,614 33,725 The Corporation had $51 billion of indefinitely reinvested, undistributed earnings from subsid iary companies outside the U.S. that were retained to fund prior and future capital project expenditures. Deferred taxes have not been recorded for potential future tax obligations as these earnings are expected to be indefinitely reinvested for the foreseeable future. As of December 31, 2015, it is not practical to estimate the unrecognized deferred tax liability associated with these earnings given the future availability of foreign tax credits and uncertainties about the timing of potential remittances 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 2015 2014 2013 (millions of dollars) Balance at January 1 8,986 7,838 7,663 Additions based on current year's tax positions 903 1,454 1,460 Additions for prior years' tax positions 496 448 464 Reductions for prior years' tax positions (190) (532) (249) Reductions due to lapse of the statute of limitations (4) (117) (588) Settlements with tax authorities (725) (43) (849) Foreign exchange effects/other (70) (62) (63) Balance at December 31 9,396 8,986 7,838 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 201 5 , 201 4 and 201 3 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 authoritie s 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. In the United States, the Corporation has various U.S. federal income tax positions at issue with the Internal Revenue Service for tax years 2006-2011. U nfavorable resolution of these issues would not have a materially adverse effect on the Corporation’s net income or liquidity. The Internal Revenue Service has not completed it s audit of tax years after 2011. It is reasonably possible that the total amount of unrecognized tax benefits could increase by up to 20 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 - 2015 Angola 2009 - 2015 Australia 2005, 2008 - 2015 Canada 2008 - 2015 Equatorial Guinea 2007 - 2015 Malaysia 2009 - 2015 Nigeria 2005 - 2015 Norway 2007 - 2015 Qatar 2009 - 2015 Russia 2012 - 2015 United Kingdom 2011 - 2015 United States 2006 - 2015 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 $39 million and $42 million in interest expense on income tax reserves in 2015 and 2014, respectively. 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 relat ed interest payable balances were $223 million and $205 million at December 31, 201 5 , and 201 4 , respectively.

Summary Of Accounting Policies

Summary Of Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2015
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 Cor poration’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 consolid ated. 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 contrac t 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 transl ation 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 reser ves, 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 pr ices 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 ow nership, 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 w orking 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 exc hanges 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	Deriv ative 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 resul ting 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 t he 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 p riority 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 tha t are directly or indirectly observable for the asse t 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. Selli ng 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, b ased 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. E xploratory well costs are carried as an asset w hen 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 c osts of productive wells and development dry holes , are c apitalized. 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 uni t-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. In the event that the unit-of-production method does not result in an equitable allocation of cost over the economic life of an upstream asset, an alternative such as the straight-line method is used. Production involves lifting the oil and gas to the surface and gathering, treating, field proce ssing 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 equip ment 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 maintenanc e 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. The Corporation performs impairment assessments whenever events o r circumstances indicate that the carrying amounts of its long-lived assets (or group of assets) may not be recoverable through future operations or disposition. Assets are grouped at the lowest level for which there are identifiable cash flows that are la rgely independent of the cash flows of other groups of assets for this assessment. Potential trigger events for impairment evaluation include: a significant decrease in the market price of a long-lived asset; a significant adverse change in the extent or manner in which an asset is being used or in its physical condition including a significant decrease in current and projected reserve volumes; a significant adverse change in legal factors or in the business cli mate that could affect the value, including an adverse action or assessment by a regulator; an accumulation of project costs significantly in excess of the amount originally expected; a current-period operating loss combined with a history and forecast of operating or cash flow losses; and a current expectation that, more likely than not, a long-lived asset will be sold or otherwise disposed of significantly before the end of its previously estimated useful life. The Corporation performs asset valuation ana lyses on an ongoing basis as a part of its asset management program. These analyses and other profitability reviews assist the Corporation in assessing whether the carrying amounts of any of its assets may not be recoverable. In general, the Corporation do es not view temporarily low prices or margins as a trigger event for conducting impairment tests. The markets for crude oil, natural gas and petroleum products, have a history of significant price volatility. Although prices will occasionally drop signific antly, industry prices over the l ong term will continue to be driven by market supply and demand. On the supply side, industry production from mature fields is declining, but this is being offset by production from new discoveries and field developments. OPEC production policies also have an impact on world oil supplies. The demand side is largely a function of global economic growth. The relative growth/decline in supply versus demand will determine industry prices over the long term, and these cannot be accurately predicted. If there were a trigger event, 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 est imates for future crude oil and natural gas commodity prices, refining and chemical margins, and foreign currency exchange rates. Volumes are based on projected field and facility production profiles, throughput, or sales. These evaluations make use of the Corporation’s price, margin, volume, and cost assumptions developed in the annual planning and budgeting process, and are consistent with the criteria management uses to evaluate investment opportunities. Where unproved reserves exist, an appropriately ri sk-adjusted amount of these reserves may be included in the evaluation. An asset group would be impaired if its undiscounted cash flows were less than the asset’s carrying value. Impairments are measured by the amount by which the carrying value exceeds fa ir value. Cash flow estimates for impairment testing exclude the effects of derivative instruments. Significant unproved properties are assessed for impairment individually, and valuation allowances against the capitalized costs are recorded based on the e stimated 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. G ains 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 n or any substantial obligation for future performance by the Corporation. Losses on prope rties 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 c apitalized 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. Capitaliz ed 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. Ove r 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 red uced 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 prim ary 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, whi ch 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 U pstream 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 Infor29

Miscellaneous Financial Information (Tables)	12 Months Ended
	Dec. 31, 2015
Miscellaneous Financial Information [Abstract]
Crude Oil, Products And Merchandise	2015 2014 (billions of dollars) Crude oil 4.2 4.6 Petroleum products 4.1 4.1 Chemical products 2.7 2.9 Gas/other 1.0 0.8 Total 12.0 12.4

Other Comprehensive Income In30

Other Comprehensive Income Information (Tables)	12 Months Ended
	Dec. 31, 2015
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, 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) Balance as of December 31, 2014 (5,952) (12,945) (60) (18,957) Current period change excluding amounts reclassified from accumulated other comprehensive income (8,204) 2,202 33 (5,969) Amounts reclassified from accumulated other comprehensive income (14) 1,402 27 1,415 Total change in accumulated other comprehensive income (8,218) 3,604 60 (4,554) Balance as of December 31, 2015 (14,170) (9,341) - (23,511)
Reclassification Out Of Accumulated Other Comprehensive Income	Amounts Reclassified Out of Accumulated Other Comprehensive Income - Before-tax Income/(Expense) 2015 2014 2013 (millions of dollars) Foreign exchange translation gain/(loss) included in net income (Statement of Income line: Other income) 14 (152) 23 Amortization and settlement of postretirement benefits reserves adjustment included in net periodic benefit costs (1) (2,066) (1,571) (2,616) Realized change in fair value of stock investments included in net income (Statement of Income line: Other income) (42) (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.)
Schedule Of Income Tax (Expense)/Credit For Components Of Other Comprehensive Income	Income Tax (Expense)/Credit For Components of Other Comprehensive Income 2015 2014 2013 (millions of dollars) Foreign exchange translation adjustment 170 292 218 Postretirement benefits reserves adjustment (excluding amortization) (1,192) 2,009 (1,540) Amortization and settlement of postretirement benefits reserves adjustment included in net periodic benefit costs (618) (460) (796) Unrealized change in fair value of stock investments (17) 34 - Realized change in fair value of stock investments included in net income (15) (2) - Total (1,672) 1,873 (2,118)

Cash Flow Information (Tables)

Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2015
Cash Flow Information [Abstract]
Cash payments for interest and income taxes	2015 2014 2013 (millions of dollars) Cash payments for interest 586 380 426 Cash payments for income taxes 7,269 18,085 25,066

Additional Working Capital In32

Additional Working Capital Information (Tables)	12 Months Ended
	Dec. 31, 2015
Additional Working Capital Information [Abstract]
Schedule Of Notes, Accounts Receivable And Payable, Loans Payable, And Accrued Liabilities	Dec. 31 Dec. 31 2015 2014 (millions of dollars) Notes and accounts receivable Trade, less reserves of $107 million and $113 million 13,243 18,541 Other, less reserves of $4 million and $48 million 6,632 9,468 Total 19,875 28,009 Notes and loans payable Bank loans 231 473 Commercial paper 17,973 16,225 Long-term debt due within one year 558 770 Total 18,762 17,468 Accounts payable and accrued liabilities Trade payables 18,074 25,286 Payables to equity companies 4,639 6,589 Accrued taxes other than income taxes 2,937 3,290 Other 6,762 7,062 Total 32,412 42,227

Equity Company Information (Tab

Equity Company Information (Tables)	12 Months Ended
	Dec. 31, 2015
Equity Company Information [Abstract]
Schedule Of Equity Company Financial Summary	2015 2014 2013 Equity Company ExxonMobil ExxonMobil ExxonMobil Financial Summary Total Share Total Share Total Share (millions of dollars) Total revenues 111,866 34,297 183,708 55,855 236,161 68,084 Income before income taxes 36,379 10,670 65,549 19,014 69,454 19,999 Income taxes 11,048 3,019 20,520 5,684 21,618 6,069 Income from equity affiliates 25,331 7,651 45,029 13,330 47,836 13,930 Current assets 32,879 11,244 49,905 16,802 62,398 19,545 Long-term assets 109,684 32,878 110,754 33,619 116,450 35,695 Total assets 142,563 44,122 160,659 50,421 178,848 55,240 Current liabilities 22,947 6,738 37,333 11,472 54,550 15,243 Long-term liabilities 60,388 17,165 66,231 19,470 68,857 20,873 Net assets 59,228 20,219 57,095 19,479 55,441 19,124
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 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 Italia s.r.l. 50 Infineum USA L.P. 50 Saudi Yanbu Petrochemical Co. 50

Investments, Advances And Lon34

Investments, Advances And Long-Term Receivables (Tables)	12 Months Ended
	Dec. 31, 2015
Investments, Advances And Long-Term Receivables [Abstract]
Schedule Of Investments, Advances And Long-Term Receivables	Dec. 31, Dec. 31, 2015 2014 (millions of dollars) Companies carried at equity in underlying assets Investments 20,337 20,017 Advances 9,110 9,818 Total equity company investments and advances 29,447 29,835 Companies carried at cost or less and stock investments carried at fair value 274 526 Long-term receivables and miscellaneous investments at cost or less, net of reserves of $3,040 million and $2,662 million 4,524 4,878 Total 34,245 35,239

Property, Plant And Equipment35

Property, Plant And Equipment And Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2015
Property, Plant And Equipment And Asset Retirement Obligations [Abstract]
Property, Plant And Equipment	December 31, 2015 December 31, 2014 Property, Plant and Equipment Cost Net Cost Net (millions of dollars) Upstream 347,821 203,822 347,170 205,308 Downstream 50,742 21,330 53,327 22,639 Chemical 32,481 16,247 30,717 14,918 Other 16,293 10,206 15,575 9,803 Total 447,337 251,605 446,789 252,668
Asset Retirement Obligations	2015 2014 (millions of dollars) Beginning balance 13,424 12,988 Accretion expense and other provisions 775 871 Reduction due to property sales (208) (151) Payments made (928) (724) Liabilities incurred 283 122 Foreign currency translation (931) (908) Revisions 1,289 1,226 Ending balance 13,704 13,424

Accounting For Suspended Expl36

Accounting For Suspended Exploratory Well Costs (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting For Suspended Exploratory Well Costs [Abstract]
Change In Capitalized Suspended Exploratory Well Costs	2015 2014 2013 (millions of dollars) Balance beginning at January 1 3,587 2,707 2,679 Additions pending the determination of proved reserves 847 1,095 293 Charged to expense (5) (28) (52) Reclassifications to wells, facilities and equipment based on the determination of proved reserves (43) (160) (107) Divestments/Other (14) (27) (106) Ending balance at December 31 4,372 3,587 2,707 Ending balance attributed to equity companies included above 696 645 13
Period End Capitalized Suspended Exploratory Well Costs	2015 2014 2013 (millions of dollars) Capitalized for a period of one year or less 847 1,095 293 Capitalized for a period of between one and five years 2,386 1,659 1,705 Capitalized for a period of between five and ten years 826 544 470 Capitalized for a period of greater than ten years 313 289 239 Capitalized for a period greater than one year - subtotal 3,525 2,492 2,414 Total 4,372 3,587 2,707
Number Of Projects With Suspended Exploratory Well Costs	2015 2014 2013 Number of projects with first capitalized well drilled in the preceding 12 months 4 8 8 Number of projects that have exploratory well costs capitalized for a period of greater than 12 months 55 53 50 Total 59 61 58
Additional Detail For Projects With Completed Exploratory Activity Progressing Toward Development	Years Dec. 31, Wells Country/Project 2015 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 7 2001 Gas field near Kipper/Tuna development, awaiting capacity in existing/planned infrastructure. - SE Longtom 11 2010 Gas field near Tuna development, awaiting capacity in existing/planned infrastructure. - SE Remora 34 2010 Gas field near Marlin development, awaiting capacity in existing/planned infrastructure. Canada - Horn River 241 2009 - 2012 Evaluating development alternatives to tie into planned infrastructure. Indonesia - Alas Tua West 16 2010 Evaluating development plan to tie into planned production facilities. - Cepu Gas 29 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. - Kalamkas 18 2006 - 2009 Evaluating development alternatives, while continuing discussions with the government regarding development plan. Malaysia - 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. - 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 13 2008 - 2009 Evaluating development plan for tieback to existing production facilities. - Lavrans 15 1995 - 1999 Evaluating development plan, awaiting capacity in existing Kristin production facility. - Other (7 projects) 25 2008 - 2014 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. 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 2015 (37 projects) 1,154

Leased Facilities (Tables)

Leased Facilities (Tables)	12 Months Ended
	Dec. 31, 2015
Leased Facilities [Abstract]
Leased Facilities	Lease Payments Under Minimum Commitments Related Drilling Rigs Sublease and Related Rental Equipment Other Total Income (millions of dollars) 2016 827 826 1,653 7 2017 408 595 1,003 6 2018 134 421 555 2 2019 89 255 344 2 2020 77 188 265 2 2021 and beyond 86 971 1,057 13 Total 1,621 3,256 4,877 32
Net Rental Cost	2015 2014 2013 (millions of dollars) Rental cost Drilling rigs and related equipment 1,853 1,763 1,424 Other 2,120 2,314 2,417 Total 3,973 4,077 3,841 Less sublease rental income 44 52 44 Net rental cost 3,929 4,025 3,797

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Share Computation	2015 2014 2013 Earnings per common share Net income attributable to ExxonMobil (millions of dollars) 16,150 32,520 32,580 Weighted average number of common shares outstanding (millions of shares) 4,196 4,282 4,419 Earnings per common share (dollars) (1) 3.85 7.60 7.37 Dividends paid per common share (dollars) 2.88 2.70 2.46 (1) The earnings per common share and earnings per common share - assuming dilution are the same in each period shown .

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Long-Term Debt [Abstract]
Summarized Long-Term Debt	2015 2014 (millions of dollars) Exxon Mobil Corporation 0.921% notes due 2017 1,500 1,500 Floating-rate notes due 2017 (1) 750 750 Floating-rate notes due 2018 (2) 500 - 1.305% notes due 2018 1,600 - 1.819% notes due 2019 1,750 1,750 Floating-rate notes due 2019 (3) 500 500 1.912% notes due 2020 1,500 - 2.397% notes due 2022 1,150 - Floating-rate notes due 2022 (4) 500 - 3.176% notes due 2024 1,000 1,000 2.709% notes due 2025 1,750 - 3.567% notes due 2045 1,000 - XTO Energy Inc. (5) 5.650% senior notes due 2016 - 207 6.250% senior notes due 2017 465 477 5.500% senior notes due 2018 377 383 6.500% senior notes due 2018 463 474 6.100% senior notes due 2036 198 199 6.750% senior notes due 2037 307 309 6.375% senior notes due 2038 235 236 Mobil Producing Nigeria Unlimited (6) Variable notes due 2016-2019 101 399 Esso (Thailand) Public Company Ltd. (7) Variable notes due 2016-2020 83 121 Mobil Corporation 8.625% debentures due 2021 249 249 Industrial revenue bonds due 2017-2051 (8) 2,611 2,611 Other U.S. dollar obligations (9) 97 104 Other foreign currency obligations 1 9 Capitalized lease obligations (10) 1,238 375 Total long-term debt 19,925 11,653 (1) Average effect ive interest rate of 0.3% in 2015 and 0.3% in 2014. (2) Average effecti ve interest rate of 0.4% in 2015 . (3 ) Average effective inter est rate of 0.5% in 2015 and 0.4 % in 2014. (4 ) Averag e effective interest rate of 0.7 % in 2015. (5) Includes premiums of $ 179 million in 2015 and $219 million in 2014 . (6) Average effective interest rate of 4.6 % in 201 5 and 4.5% in 2014 . (7) Average effective interest rate of 2.1 % in 201 5 and 2.4% in 2014 . (8) Average effective interest rate of 0.02 % i n 201 5 and 0.03% in 2014 . (9) Average effective interest rate of 3.8 % in 201 5 and 4.2% in 2014. (10) Average imputed interest rate of 9.2% in 2015 and 7.0 % in 201 4 .

Incentive Program (Tables)

Incentive Program (Tables)	12 Months Ended
	Dec. 31, 2015
Incentive Program [Abstract]
Summary Of Restricted Stock And Units Outstanding	2015 Weighted Average Grant-Date Restricted stock and units outstanding Shares Fair Value per Share (thousands) (dollars) Issued and outstanding at January 1 44,439 81.45 2014 award issued in 2015 9,758 95.20 Vested (9,945) 79.86 Forfeited (189) 82.26 Issued and outstanding at December 31 44,063 84.85
Grant Value Of Restricted Stock And Units	Value of restricted stock and units 2015 2014 2013 Grant price (dollars) 81.27 95.20 94.47 Value at date of grant: (millions of dollars) Restricted stock and units settled in stock 727 858 843 Units settled in cash 60 73 76 Total value 787 931 919

Litigation And Other Continge41

Litigation And Other Contingencies (Tables)	12 Months Ended
	Dec. 31, 2015
Litigation And Other Contingencies [Abstract]
Schedule Of Guarantees	Dec. 31, 2015 Equity Company Other Third-Party Obligations (1) Obligations Total (millions of dollars) Guarantees Debt-related 98 35 133 Other 2,539 4,553 7,092 Total 2,637 4,588 7,225 (1) ExxonMobil share.
Unconditional Purchase Obligations	Payments Due by Period 2017- 2021 and 2016 2020 Beyond Total (millions of dollars) Unconditional purchase obligations (1) 133 493 310 936 (1) Undiscounted obligations of $936 million mainly pertain to pipeline throughput agreements and include $411 million of obligations to equity companies. The present value of these commitments, which excludes imputed interest of $144 million, totaled $792 million.

Pension And Other Postretirem42

Pension And Other Postretirement Benefits (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2015 2014 2015 2014 (percent) Weighted-average assumptions used to determine benefit obligations at December 31 Discount rate 4.25 4.00 3.60 3.10 4.25 4.00 Long-term rate of compensation increase 5.75 5.75 4.80 5.30 5.75 5.75 (millions of dollars) Change in benefit obligation Benefit obligation at January 1 20,529 17,304 30,047 27,357 9,436 7,868 Service cost 864 677 689 590 170 140 Interest cost 785 807 850 1,138 346 383 Actuarial loss/(gain) (545) 3,192 (1,517) 4,929 (617) 1,522 Benefits paid (1) (2) (2,050) (1,427) (1,287) (1,366) (482) (525) Foreign exchange rate changes - - (3,242) (2,540) (106) (48) Amendments, divestments and other - (24) (423) (61) (465) 96 Benefit obligation at December 31 19,583 20,529 25,117 30,047 8,282 9,436 Accumulated benefit obligation at December 31 15,666 16,385 22,362 26,318 - - (1) Benefit payments for funded and unfunded plans. (2) For 201 5 and 201 4 , other postretirement benefits paid are net of $15 million and $ 21 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 2015 2014 2015 2014 2015 2014 (millions of dollars) Change in plan assets Fair value at January 1 12,915 11,190 20,095 19,283 468 620 Actual return on plan assets (307) 1,497 918 3,153 - 41 Foreign exchange rate changes - - (2,109) (1,738) - - Company contribution - 1,476 515 554 42 31 Benefits paid (1) (1,623) (1,248) (890) (912) (96) (224) Other - - (112) (245) - - Fair value at December 31 10,985 12,915 18,417 20,095 414 468 (1) Benefit payments for funded plans.
Summary Of Assets In Excess Of/(Less Than) Benefit Obligation	Pension Benefits U.S. Non-U.S. 2015 2014 2015 2014 (millions of dollars) Assets in excess of/(less than) benefit obligation Balance at December 31 Funded plans (5,782) (4,590) (588) (2,113) Unfunded plans (2,816) (3,024) (6,112) (7,839) Total (8,598) (7,614) (6,700) (9,952)
Amounts Recorded In Balance Sheet And Other Comprehensive Income	Pension Benefits Other Postretirement U.S. Non-U.S. Benefits 2015 2014 2015 2014 2015 2014 (millions of dollars) Assets in excess of/(less than) benefit obligation Balance at December 31 (1) (8,598) (7,614) (6,700) (9,952) (7,868) (8,968) Amounts recorded in the consolidated balance sheet consist of: Other assets - - 454 302 - - Current liabilities (311) (340) (299) (325) (363) (369) Postretirement benefits reserves (8,287) (7,274) (6,855) (9,929) (7,505) (8,599) Total recorded (8,598) (7,614) (6,700) (9,952) (7,868) (8,968) Amounts recorded in accumulated other comprehensive income consist of: Net actuarial loss/(gain) 6,138 6,589 6,413 9,642 2,171 2,997 Prior service cost 21 27 (83) 429 (460) 51 Total recorded in accumulated other comprehensive income 6,159 6,616 6,330 10,071 1,711 3,048 (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 2015 2014 2013 2015 2014 2013 2015 2014 2013 Weighted-average assumptions used to determine net periodic benefit cost for years ended December 31 (percent) Discount rate 4.00 5.00 4.00 3.10 4.30 3.80 4.00 5.00 4.00 Long-term rate of return on funded assets 7.00 7.25 7.25 5.90 6.30 6.40 7.00 7.25 7.25 Long-term rate of compensation increase 5.75 5.75 5.75 5.30 5.40 5.50 5.75 5.75 5.75 Components of net periodic benefit cost (millions of dollars) Service cost 864 677 801 689 590 697 170 140 176 Interest cost 785 807 749 850 1,138 1,076 346 383 352 Expected return on plan assets (830) (799) (835) (1,094) (1,193) (1,128) (28) (37) (41) Amortization of actuarial loss/(gain) 544 409 646 730 628 852 206 116 228 Amortization of prior service cost 6 8 7 87 120 117 (24) 14 21 Net pension enhancement and curtailment/settlement cost 499 276 723 22 - 22 - - - Net periodic benefit cost 1,868 1,378 2,091 1,284 1,283 1,636 670 616 736 Changes in amounts recorded in accumulated other comprehensive income: Net actuarial loss/(gain) 592 2,494 (1,302) (1,375) 2,969 (1,938) (589) 1,518 (1,290) Amortization of actuarial (loss)/gain (1,043) (685) (1,369) (752) (628) (874) (206) (116) (228) Prior service cost/(credit) - (25) - (401) (70) 30 (535) - - Amortization of prior service (cost)/credit (6) (8) (7) (87) (120) (117) 24 (14) (21) Foreign exchange rate changes - - - (1,126) (688) (155) (31) (8) (10) Total recorded in other comprehensive income (457) 1,776 (2,678) (3,741) 1,463 (3,054) (1,337) 1,380 (1,549) Total recorded in net periodic benefit cost and other comprehensive income, before tax 1,411 3,154 (587) (2,457) 2,746 (1,418) (667) 1,996 (813)
Summary Of Change In Accumulated Other Comprehensive Income	Total Pension and Other Postretirement Benefits 2015 2014 2013 (millions of dollars) (Charge)/credit to other comprehensive income, before tax U.S. pension 457 (1,776) 2,678 Non-U.S. pension 3,741 (1,463) 3,054 Other postretirement benefits 1,337 (1,380) 1,549 Total (charge)/credit to other comprehensive income, before tax 5,535 (4,619) 7,281 (Charge)/credit to income tax (see Note 4) (1,810) 1,549 (2,336) (Charge)/credit to investment in equity companies 81 (81) 49 (Charge)/credit to other comprehensive income including noncontrolling interests, after tax 3,806 (3,151) 4,994 Charge/(credit) to equity of noncontrolling interests (202) 85 (279) (Charge)/credit to other comprehensive income attributable to ExxonMobil 3,604 (3,066) 4,715
Fair Value Of The Benefit Plan Assets (Pension)	U.S. Pension Non-U.S. Pension Fair Value Measurement Fair Value Measurement at December 31, 2015, Using: at December 31, 2015, Using: Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (millions of dollars) Asset category: Equity securities U.S. - 1,992 (1) - 1,992 - 3,179 (1) - 3,179 Non-U.S. - 1,775 (1) - 1,775 179 (2) 3,429 (1) - 3,608 Private equity - - 595 (3) 595 - - 581 (3) 581 Debt securities Corporate - 4,161 (4) - 4,161 - 2,561 (4) - 2,561 Government - 2,394 (4) - 2,394 243 (5) 8,125 (4) - 8,368 Asset-backed - 3 (4) - 3 - 71 (4) - 71 Real estate funds - - - - - - - - Cash - 50 (6) - 50 11 12 (7) - 23 Total at fair value - 10,375 595 10,970 433 17,377 581 18,391 Insurance contracts at contract value 15 26 Total plan assets 10,985 18,417 ( 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 excha nges, 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 gove rnment debt securities that are traded on active exchanges, fair value is based on observable quoted prices. (6 ) 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. (7 ) 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, 2014, Using: at December 31, 2014, Using: 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 .
Fair Value Of The Benefit Plan Assets (Other Postretirement)	Other Postretirement Fair Value Measurement at December 31, 2015, Using: Level 1 Level 2 Level 3 Total (millions of dollars) Asset category: Equity securities U.S. - 96 (1) - 96 Non-U.S. - 67 (1) - 67 Private equity - - - - Debt securities Corporate - 79 (2) - 79 Government - 170 (2) - 170 Asset-backed - 1 (2) - 1 Cash - 1 - 1 Total at fair value - 414 - 414 (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 ac tive excha nges, 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. Other Postretirement Fair Value Measurement at December 31, 2014, Using: 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 (1) For U.S. and non-U.S. equity securities held in the form of fund units that are redeemable at the measurement date, the unit value is treated as a Level 2 input. The fair value of the securities owned by the funds is based on observable quoted prices on active exchanges, which are Level 1 inputs. (2) For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings. (3) For corporate, government and asset-backed debt securities, fair value is based on observable inputs of comparable market transactions.
Change In Fair Value Of Level 3 Assets	2015 Pension Other U.S. Non-U.S. Postretirement Private Private Real Private Equity Equity Estate Equity (millions of dollars) Fair value at January 1 562 535 57 2 Net realized gains/(losses) 1 26 (5) - Net unrealized gains/(losses) 106 64 - - Net purchases/(sales) (74) (44) (52) (2) Fair value at December 31 595 581 - - 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
Pension Plans With Accumulated Benefit Obligation In Excess Of Plan Assets	Pension Benefits U.S. Non-U.S. 2015 2014 2015 2014 (millions of dollars) For funded pension plans with an accumulated benefit obligation in excess of plan assets: Projected benefit obligation 16,767 17,505 1,827 5,031 Accumulated benefit obligation 13,913 14,493 1,373 4,590 Fair value of plan assets 10,985 12,915 1,299 3,890 For unfunded pension plans: Projected benefit obligation 2,816 3,024 6,112 7,839 Accumulated benefit obligation 1,753 1,892 5,290 6,573
Estimated Next Year Amortization	Other Pension Benefits Postretirement U.S. Non-U.S. Benefits (millions of dollars) Estimated 2016 amortization from accumulated other comprehensive income: Net actuarial loss/(gain) (1) 930 543 152 Prior service cost (2) 6 55 (30) (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 2016 2,000 525 - - Benefit payments expected in: 2016 1,548 1,145 457 24 2017 1,491 1,128 470 25 2018 1,411 1,178 481 26 2019 1,382 1,193 490 28 2020 1,342 1,227 497 29 2021 - 2025 6,594 6,359 2,518 170

Disclosures About Segments An43

Disclosures About Segments And Related Information (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2015 Earnings after income tax (1,079) 8,180 1,901 4,656 2,386 2,032 (1,926) 16,150 Earnings of equity companies included above 226 5,831 170 444 144 1,235 (406) 7,644 Sales and other operating revenue (1) 8,241 15,812 73,063 134,230 10,880 17,254 8 259,488 Intersegment revenue 4,344 20,839 12,440 22,166 7,442 5,168 274 - Depreciation and depletion expense 5,301 9,227 664 1,003 375 654 824 18,048 Interest revenue - - - - - - 46 46 Interest expense 26 27 8 4 - 1 245 311 Income taxes (879) 4,703 866 1,325 646 633 (1,879) 5,415 Additions to property, plant and equipment 6,915 14,561 916 1,477 1,865 629 1,112 27,475 Investments in equity companies 5,160 10,980 95 1,179 125 3,025 (227) 20,337 Total assets 93,648 155,316 16,498 29,808 10,174 18,236 13,078 336,758 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 (1) Sales and other operating revenue includes sales-based taxes of $22,678 million for 2015, $29,342 million for 2014 and $30 , 589 million for 201 3 . See Note 1, Summary of Accounting Policies.
Geographic Sales And Other Operating Revenue	Geographic Sales and other operating revenue (1) 2015 2014 2013 (millions of dollars) United States 92,184 148,713 152,820 Non-U.S. 167,304 245,392 268,016 Total 259,488 394,105 420,836 Significant non-U.S. revenue sources include: United Kingdom 23,651 31,346 34,061 Canada 22,876 36,072 35,924 Italy 13,795 18,880 19,273 Belgium 13,154 20,953 20,973 France 11,808 17,639 18,444 Singapore 10,790 15,407 15,623 Germany 10,045 14,816 15,701 (1) Sales and other operating revenue includes sales-based taxes of $22,678 million for 2015, $29,342 million for 2014 and $30,589 million for 2013. See Note 1, Summary of Accounting Policies.
Schedule Of Long-Lived Assets By Geographic Regions	Long-lived assets 2015 2014 2013 (millions of dollars) United States 107,039 104,000 98,271 Non-U.S. 144,566 148,668 145,379 Total 251,605 252,668 243,650 Significant non-U.S. long-lived assets include: Canada 39,775 43,858 41,522 Australia 15,894 15,328 14,258 Nigeria 12,222 12,265 12,343 Kazakhstan 9,705 9,138 8,530 Singapore 9,681 9,620 9,570 Angola 8,777 9,057 8,262 Papua New Guinea 5,985 6,099 5,768

Income, Sales-Based And Other44

Income, Sales-Based And Other Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income, Sales-Based And Other Taxes [Abstract]
Schedule Of Income, Sales-Based And Other Taxes	2015 2014 2013 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 - 7,126 7,126 1,456 14,755 16,211 1,073 22,115 23,188 Deferred - net (1,166) (571) (1,737) 900 1,398 2,298 (116) 757 641 U.S. tax on non-U.S. operations 38 - 38 5 - 5 37 - 37 Total federal and non-U.S. (1,128) 6,555 5,427 2,361 16,153 18,514 994 22,872 23,866 State (1) (12) - (12) (499) - (499) 397 - 397 Total income tax expense (1,140) 6,555 5,415 1,862 16,153 18,015 1,391 22,872 24,263 Sales-based taxes 6,402 16,276 22,678 6,310 23,032 29,342 5,992 24,597 30,589 All other taxes and duties Other taxes and duties 162 27,103 27,265 378 31,908 32,286 955 32,275 33,230 Included in production and manufacturing expenses 1,157 828 1,985 1,454 1,179 2,633 1,318 1,182 2,500 Included in SG&A expenses 150 390 540 155 441 596 150 516 666 Total other taxes and duties 1,469 28,321 29,790 1,987 33,528 35,515 2,423 33,973 36,396 Total 6,731 51,152 57,883 10,159 72,713 82,872 9,806 81,442 91,248 (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	2015 2014 2013 (millions of dollars) Income before income taxes United States 147 9,080 9,746 Non-U.S. 21,819 42,550 47,965 Total 21,966 51,630 57,711 Theoretical tax 7,688 18,071 20,199 Effect of equity method of accounting (2,675) (4,663) (4,874) Non-U.S. taxes in excess of theoretical U.S. tax 1,415 5,442 10,528 U.S. tax on non-U.S. operations 38 5 37 State taxes, net of federal tax benefit (8) (324) 258 Other (1,043) (516) (1,885) Total income tax expense 5,415 18,015 24,263 Effective tax rate calculation Income taxes 5,415 18,015 24,263 ExxonMobil share of equity company income taxes 3,011 5,678 6,061 Total income taxes 8,426 23,693 30,324 Net income including noncontrolling interests 16,551 33,615 33,448 Total income before taxes 24,977 57,308 63,772 Effective income tax rate 34% 41% 48%
Deferred Tax Liabilities/(Assets)	Tax effects of temporary differences for: 2015 2014 (millions of dollars) Property, plant and equipment 49,409 51,643 Other liabilities 4,613 4,359 Total deferred tax liabilities 54,022 56,002 Pension and other postretirement benefits (6,286) (8,140) Asset retirement obligations (6,277) (6,162) Tax loss carryforwards (4,983) (4,099) Other assets (5,592) (6,446) Total deferred tax assets (23,138) (24,847) Asset valuation allowances 1,730 2,570 Net deferred tax liabilities 32,614 33,725
Deferred Income Tax (Assets) And Liabilities By Balance Sheet Classification	Balance sheet classification 2015 2014 (millions of dollars) Other current assets (1,329) (2,001) Other assets, including intangibles, net (3,421) (3,955) Accounts payable and accrued liabilities 546 451 Deferred income tax liabilities 36,818 39,230 Net deferred tax liabilities 32,614 33,725
Unrecognized Tax Benefits	Gross unrecognized tax benefits 2015 2014 2013 (millions of dollars) Balance at January 1 8,986 7,838 7,663 Additions based on current year's tax positions 903 1,454 1,460 Additions for prior years' tax positions 496 448 464 Reductions for prior years' tax positions (190) (532) (249) Reductions due to lapse of the statute of limitations (4) (117) (588) Settlements with tax authorities (725) (43) (849) Foreign exchange effects/other (70) (62) (63) Balance at December 31 9,396 8,986 7,838
Remaining Tax Years Subject To Examination By Major Tax Jurisdiction	Country of Operation Open Tax Years Abu Dhabi 2012 - 2015 Angola 2009 - 2015 Australia 2005, 2008 - 2015 Canada 2008 - 2015 Equatorial Guinea 2007 - 2015 Malaysia 2009 - 2015 Nigeria 2005 - 2015 Norway 2007 - 2015 Qatar 2009 - 2015 Russia 2012 - 2015 United Kingdom 2011 - 2015 United States 2006 - 2015

Miscellaneous Financial Infor45

Miscellaneous Financial Information (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Miscellaneous Financial Information [Abstract]
Research and development expense	$ 1,008,000,000	$ 971,000,000	$ 1,044,000,000
Foreign currency transaction gain/(loss), before tax	(119,000,000)	(225,000,000)	155,000,000
Gains/(losses) on combined effects of LIFO inventory accumulations and draw-downs	(186,000,000)	187,000,000	$ 282,000,000
Replacement cost of inventories estimated to exceed LIFO carrying values	$ 4,500,000,000	$ 10,600,000,000

Miscellaneous Financial Infor46

Miscellaneous Financial Information (Crude Oil, Products And Merchandise) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Miscellaneous Financial Information [Abstract]
Crude oil	$ 4,200	$ 4,600
Petroleum products	4,100	4,100
Chemical products	2,700	2,900
Gas / other	1,000	800
Total	$ 12,037	$ 12,384

Other Comprehensive Income In47

Other Comprehensive Income Information (Schedule of Accumulated Other Comprehensive Income Information) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current period change excluding amounts reclassified from accumulated other comprehensive income, Cumulative Foreign Exchange Translation Adjustment	$ (9,303)	$ (5,847)	$ (3,620)
Amounts reclassified from accumulated other comprehensive income, Cumulative Foreign Exchange Translation Adjustment	(14)	152	(23)
Current period change excluding amounts reclassified from accumulated other comprehensive income, Postretirement Benefits Reserves Adjustment	2,358	(4,262)	3,174
Amounts reclassified from accumulated other comprehensive income, Postretirement Benefits Reserves Adjustment	1,448	1,111	1,820
Current period change excluding amounts reclassified from accumulated other comprehensive income, Unrealized Change in Stock Investments	33	(63)
Amounts reclassified from accumulated other comprehensive income, Unrealized Change in Stock Investments	27	3
Beginning Balance, Total	(18,957)
Ending Balance, Total	(23,511)	(18,957)
Exxon Mobil Corporation Share After Noncontrolling Interest [Member]
Beginning Balance, Cumulative Foreign Exchange Translation Adjustment	(5,952)	(846)	2,410
Current period change excluding amounts reclassified from accumulated other comprehensive income, Cumulative Foreign Exchange Translation Adjustment	(8,204)	(5,258)	(3,233)
Amounts reclassified from accumulated other comprehensive income, Cumulative Foreign Exchange Translation Adjustment	(14)	152	(23)
Total change in accumulated other comprehensive income, Cumulative Foreign Exchange Translation Adjustment	(8,218)	(5,106)	(3,256)
Ending Balance, Cumulative Foreign Exchange Translation Adjustment	(14,170)	(5,952)	(846)
Beginning Balance, Postretirement Benefits Reserves Adjustment	(12,945)	(9,879)	(14,594)
Current period change excluding amounts reclassified from accumulated other comprehensive income, Postretirement Benefits Reserves Adjustment	2,202	(4,132)	2,963
Amounts reclassified from accumulated other comprehensive income, Postretirement Benefits Reserves Adjustment	1,402	1,066	1,752
Total change in accumulated other comprehensive income, Postretirement Benefits Reserves Adjustment	3,604	(3,066)	4,715
Ending Balance, Postretirement Benefits Reserves Adjustment	(9,341)	(12,945)	(9,879)
Beginning Balance, Unrealized Change in Stock Investments	(60)
Current period change excluding amounts reclassified from accumulated other comprehensive income, Unrealized Change in Stock Investments	33	(63)
Amounts reclassified from accumulated other comprehensive income, Unrealized Change in Stock Investments	27	3
Total change in accumulated other comprehensive income, Unrealized Change in Stock Investments	60	(60)
Ending Balance, Unrealized Change in Stock Investments		(60)
Beginning Balance, Total	(18,957)	(10,725)	(12,184)
Current period change excluding amounts reclassified from accumulated other comprehensive income, Total	(5,969)	(9,453)	(270)
Amounts reclassified from accumulated other comprehensive income, Total	1,415	1,221	1,729
Total other comprehensive income	(4,554)	(8,232)	1,459
Ending Balance, Total	$ (23,511)	$ (18,957)	$ (10,725)

Other Comprehensive Income In48

Other Comprehensive Income Information (Amounts Reclassified Out Of Acc Other Comp Income) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Other Comprehensive Income Information Before Tax [Abstract]
Foreign exchange translation gain/(loss) included in net income (Statement of Income line: Other income)		$ 14	$ (152)	$ 23
Amortization and settlement of postretirement benefits reserves adjustment included in net periodic benefit costs	[1]	(2,066)	(1,571)	$ (2,616)
Realized change in fair value of stock investments included in net income (Statement of Income line: Other income)		$ (42)	$ (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 In49

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, 2015	Dec. 31, 2014	Dec. 31, 2013
Other Comprehensive Income Information Tax [Abstract]
Foreign exchange translation adjustment	$ 170	$ 292	$ 218
Postretirement benefits reserves adjustment (excluding amortization)	(1,192)	2,009	(1,540)
Amortization and settlement of postretirement benefits reserves adjustment included in net periodic benefit costs	(618)	(460)	(796)
Unrealized change in fair value of stock investments	(17)	34
Realized change in fair value of stock investments included in net income	(15)	(2)
Total	$ (1,672)	$ 1,873	$ (2,118)

Cash Flow Information (Cash Pay

Cash Flow Information (Cash Payments For Interest And Income Taxes) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash Flow Information [Abstract]
Cash payments for interest	$ 586	$ 380	$ 426
Cash payments for income taxes	7,269	18,085	25,066
Proceeds from sales of assets	2,389	4,035	$ 2,707
Asset Exchange [Member]
Asset exchanges, primarily noncash	500	$ 1,200
Proceeds from sales of assets	100
Capital lease obligations incurred	1,000
Maturity Greater Than Three Months [Member]
Net cash flow from issuance/(repayment) of commercial paper	358
Proceeds from issuance of commercial paper	8,100
Repayments of commercial paper	$ 7,700

Additional Working Capital In51

Additional Working Capital Information (Narrative) (Details) - USD ($) $ in Billions	Dec. 31, 2015	Dec. 31, 2014
Line Of Credit Facility [Line Items]
Weighted-average interest rate on short-term borrowings outstanding	0.40%	0.30%
Short Term Financing [Member]
Line Of Credit Facility [Line Items]
Unused credit lines	$ 6

Additional Working Capital In52

Additional Working Capital Information (Schedule Of Notes, Accounts Receivable And Payable, Loans Payable, Accrued Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Additional Working Capital Information [Abstract]
Trade notes and accounts receivable, less reserves of $107 million and $113 million	$ 13,243	$ 18,541
Other notes and accounts receivable, less reserves of $4 million and $48 million	6,632	9,468
Total notes and accounts receivable	19,875	28,009
Bank loans	231	473
Commercial paper	17,973	16,225
Long-term debt due within one year	558	770
Total notes and loans payable	18,762	17,468
Trade payables	18,074	25,286
Payables to equity companies	4,639	6,589
Accrued taxes other than income taxes	2,937	3,290
Other accounts payable and accrued liabilities	6,762	7,062
Total accounts payable and accrued liabilities	32,412	42,227
Trade notes and accounts receivable, reserves	107	113
Other notes and accounts receivable, reserves	$ 4	$ 48

Equity Company Information (Nar

Equity Company Information (Narrative) (Details) - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of Equity Method Investments [Line Items]
Share of equity company sales revenues from sales to consolidated companies	15.00%	14.00%	13.00%
Rosneft VIE Joint Venture [Member]
Schedule of Equity Method Investments [Line Items]
Maximum before-tax exposure to loss from Rosneft JV's	$ 1

Equity Company Information (Sch

Equity Company Information (Schedule Of Equity Company Financial Summary) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Subsidiary or Equity Method Investee [Line Items]
Net assets	$ 20,337	$ 20,017	$ 19,619
ExxonMobil Share Of Equity [Member]
Subsidiary or Equity Method Investee [Line Items]
Total revenues	34,297	55,855	68,084
Income before income taxes	10,670	19,014	19,999
Income taxes	3,019	5,684	6,069
Income from equity affiliates	7,651	13,330	13,930
Current assets	11,244	16,802	19,545
Long-term assets	32,878	33,619	35,695
Total assets	44,122	50,421	55,240
Current liabilities	6,738	11,472	15,243
Long-term liabilities	17,165	19,470	20,873
Net assets	20,219	19,479	19,124
Total Equity Company Including All Owners [Member]
Subsidiary or Equity Method Investee [Line Items]
Total revenues	111,866	183,708	236,161
Income before income taxes	36,379	65,549	69,454
Income taxes	11,048	20,520	21,618
Income from equity affiliates	25,331	45,029	47,836
Current assets	32,879	49,905	62,398
Long-term assets	109,684	110,754	116,450
Total assets	142,563	160,659	178,848
Current liabilities	22,947	37,333	54,550
Long-term liabilities	60,388	66,231	68,857
Net assets	$ 59,228	$ 57,095	$ 55,441

Equity Company Information (S55

Equity Company Information (Schedule Of The Corporation's Percentage Ownership Interest) (Details)	Dec. 31, 2015
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] | 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 Italia s.r.l. [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 Lon56

Investments, Advances And Long-Term Receivables (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Investments, Advances And Long-Term Receivables [Abstract]
Investments (Companies carried at equity in underlying assets)	$ 20,337	$ 20,017	$ 19,619
Advances (Companies carried at equity in underlying assets)	9,110	9,818
Total equity company investments and advances	29,447	29,835
Companies carried at cost or less and stock investments carried at fair value	274	526
Long-term receivables and miscellaneous investments at cost or less, net of reserves of $3,040 million and $2,662 million	4,524	4,878
Total	34,245	35,239
Reserves for long-term receivables and miscellaneous investments	$ 3,040	$ 2,662

Property, Plant And Equipment57

Property, Plant And Equipment And Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Accumulated depreciation and depletion		$ 195,732	$ 194,121
Interest capitalized		$ 482	$ 344	$ 309
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	25 years	20 years

Property, Plant And Equipment58

Property, Plant And Equipment And Asset Retirement Obligations (Property, Plant And Equipment) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	$ 447,337	$ 446,789
Property, Plant and Equipment, Net	251,605	252,668	$ 243,650
Upstream [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	347,821	347,170
Property, Plant and Equipment, Net	203,822	205,308
Downstream [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	50,742	53,327
Property, Plant and Equipment, Net	21,330	22,639
Chemical [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	32,481	30,717
Property, Plant and Equipment, Net	16,247	14,918
Other [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Cost	16,293	15,575
Property, Plant and Equipment, Net	$ 10,206	$ 9,803

Property, Plant And Equipment59

Property, Plant And Equipment And Asset Retirement Obligations (Asset Retirement Obligations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Property, Plant And Equipment And Asset Retirement Obligations [Abstract]
Beginning balance	$ 13,424	$ 12,988
Accretion expense and other provisions	775	871
Reduction due to property sales	(208)	(151)
Payments made	(928)	(724)
Liabilities incurred	283	122
Foreign currency translation	(931)	(908)
Revisions	1,289	1,226
Ending balance	$ 13,704	$ 13,424

Accounting For Suspended Expl60

Accounting For Suspended Exploratory Well Costs (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2012USD ($)
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, 2015	55	53	50
Number of projects that have drilling in the preceding twelve months or exploratory activity either planned in the next two years or subject to sanctions as of December 31, 2015	18
Number of projects with completed exploratory activity progressing toward development as of December 31, 2015	37
Capitalized exploratory well costs	$ 4,372	$ 3,587	$ 2,707	$ 2,679
Total 37 Projects [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 1,154

Accounting For Suspended Expl61

Accounting For Suspended Exploratory Well Costs (Change In Capitalized Suspended Exploratory Well Costs) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Accounting For Suspended Exploratory Well Costs [Abstract]
Capitalized suspended exploratory well costs, beginning balance	$ 3,587	$ 2,707	$ 2,679
Additions pending the determination of proved reserves	847	1,095	293
Charged to expense	(5)	(28)	(52)
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	(43)	(160)	(107)
Divestments/Other	(14)	(27)	(106)
Capitalized suspended exploratory well costs, ending balance	4,372	3,587	2,707
Ending balance attributed to equity companies included above	$ 696	$ 645	$ 13

Accounting For Suspended Expl62

Accounting For Suspended Exploratory Well Costs (Schedule Of Period End Capitalized Suspended Exploratory Well Costs) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized for a period of one year or less	$ 847	$ 1,095	$ 293
Capitalized for a period greater than one year - subtotal	3,525	2,492	2,414
Capitalized suspended exploratory well costs, total	4,372	3,587	2,707	$ 2,679
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 for a period greater than one year - subtotal	2,386	1,659	1,705
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 for a period greater than one year - subtotal	826	544	470
Capitalized For A Period Of Greater Than Ten Years [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized for a period greater than one year - subtotal	$ 313	$ 289	$ 239

Accounting For Suspended Expl63

Accounting For Suspended Exploratory Well Costs (Schedule Of Number Of Projects With Suspended Exploratory Well Costs) (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Accounting For Suspended Exploratory Well Costs [Abstract]
Number of projects with first capitalized well drilled in the preceding 12 months	4	8	8
Number of projects that have exploratory well costs capitalized for a period of greater than 12 months	55	53	50
Total	59	61	58

Accounting For Suspended Expl64

Accounting For Suspended Exploratory Well Costs (Schedule Of Additional Detail For The Projects) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 4,372	$ 3,587	$ 2,707	$ 2,679
Total 37 Projects [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	1,154
Angola [Member] | Project In Angola - Kaombo Split Hub Phase 2[Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 20
Angola [Member] | Project In Angola - Kaombo Split Hub Phase 2[Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,005
Angola [Member] | Project In Angola - Kaombo Split Hub Phase 2[Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,006
Angola [Member] | Project In Angola - Perpetua-Zinia- Acacia [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 15
Angola [Member] | Project In Angola - Perpetua-Zinia- Acacia [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,008
Angola [Member] | Project In Angola - Perpetua-Zinia- Acacia [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,009
Australia [Member] | Project In Australia - East Pilchard [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 7
Australia [Member] | Project In Australia - East Pilchard [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,001
Australia [Member] | Project In Australia - East Pilchard [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,001
Australia [Member] | Project In Australia - SE Longtom [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 11
Australia [Member] | Project In Australia - SE Longtom [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,010
Australia [Member] | Project In Australia - SE Longtom [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,010
Australia [Member] | Project in Australia - SE Remora [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 34
Australia [Member] | Project in Australia - SE Remora [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,010
Australia [Member] | Project in Australia - SE Remora [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,010
Canada [Member] | Project in Canada - Horn River
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 241
Canada [Member] | Project in Canada - Horn River | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,009
Canada [Member] | Project in Canada - Horn River | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,012
Indonesia [Member] | Project In Indonesia - Alas Tua West [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 16
Indonesia [Member] | Project In Indonesia - Alas Tua West [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,010
Indonesia [Member] | Project In Indonesia - Alas Tua West [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,010
Indonesia [Member] | Project In Indonesia - Cepu Gas [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 29
Indonesia [Member] | Project In Indonesia - Cepu Gas [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,008
Indonesia [Member] | Project In Indonesia - Cepu Gas [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,011
Indonesia [Member] | Project in Indonesia - Kedung Keris [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 11
Indonesia [Member] | Project in Indonesia - Kedung Keris [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,011
Indonesia [Member] | Project in Indonesia - Kedung Keris [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,011
Indonesia [Member] | Project In Indonesia - Natuna [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 118
Indonesia [Member] | Project In Indonesia - Natuna [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	1,981
Indonesia [Member] | Project In Indonesia - Natuna [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	1,983
Kazakhstan [Member] | Project In Kazakhstan - Kairan [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 53
Kazakhstan [Member] | Project In Kazakhstan - Kairan [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,004
Kazakhstan [Member] | Project In Kazakhstan - Kairan [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,007
Kazakhstan [Member] | Project in Kazakhstan - Kalamkas
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 18
Kazakhstan [Member] | Project in Kazakhstan - Kalamkas | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,006
Kazakhstan [Member] | Project in Kazakhstan - Kalamkas | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,009
Malaysia [Member] | Project in Malaysia - Bindu [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 2
Malaysia [Member] | Project in Malaysia - Bindu [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	1,995
Malaysia [Member] | Project in Malaysia - Bindu [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	1,995
Nigeria [Member] | Project In Nigeria - Bolia [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 15
Nigeria [Member] | Project In Nigeria - Bolia [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,002
Nigeria [Member] | Project In Nigeria - Bolia [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,006
Nigeria [Member] | Project In Nigeria - Bosi [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 79
Nigeria [Member] | Project In Nigeria - Bosi [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,002
Nigeria [Member] | Project In Nigeria - Bosi [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,006
Nigeria [Member] | Project in Nigeria - Bosi Central [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 16
Nigeria [Member] | Project in Nigeria - Bosi Central [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,006
Nigeria [Member] | Project in Nigeria - Bosi Central [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,006
Nigeria [Member] | Project in Nigeria - Erha Northeast [Member}
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 26
Nigeria [Member] | Project in Nigeria - Erha Northeast [Member} | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,008
Nigeria [Member] | Project in Nigeria - Erha Northeast [Member} | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,008
Nigeria [Member] | Project In Nigeria - Pegi [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 32
Nigeria [Member] | Project In Nigeria - Pegi [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,009
Nigeria [Member] | Project In Nigeria - Pegi [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,009
Nigeria [Member] | Project in Nigeria - Satellite Field Development Phase 2 [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 12
Nigeria [Member] | Project in Nigeria - Satellite Field Development Phase 2 [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,013
Nigeria [Member] | Project in Nigeria - Satellite Field Development Phase 2 [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,013
Nigeria [Member] | Other 4 Projects In Nigeria [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 14
Nigeria [Member] | Other 4 Projects In Nigeria [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,002
Nigeria [Member] | Other 4 Projects In Nigeria [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,002
Norway [Member] | Project in Norway - Gamma [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 13
Norway [Member] | Project in Norway - Gamma [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,008
Norway [Member] | Project in Norway - Gamma [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,009
Norway [Member] | Project In Norway - Lavrans [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 15
Norway [Member] | Project In Norway - Lavrans [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	1,995
Norway [Member] | Project In Norway - Lavrans [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	1,999
Norway [Member] | Other 7 Projects In Norway [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 25
Norway [Member] | Other 7 Projects In Norway [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,008
Norway [Member] | Other 7 Projects In Norway [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,014
Papua New Guinea [Member] | Project In Papua New Guinea - Juha [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 28
Papua New Guinea [Member] | Project In Papua New Guinea - Juha [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,007
Papua New Guinea [Member] | Project In Papua New Guinea - Juha [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,007
Republic of Congo [Member] | Project In Republic of Congo - Mer Tres Profonde Sud [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 56
Republic of Congo [Member] | Project In Republic of Congo - Mer Tres Profonde Sud [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,000
Republic of Congo [Member] | Project In Republic of Congo - Mer Tres Profonde Sud [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,007
United Kingdom [Member] | Project In United Kingdom - Phyllis [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 8
United Kingdom [Member] | Project In United Kingdom - Phyllis [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,004
United Kingdom [Member] | Project In United Kingdom - Phyllis [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,004
United States [Member] | Project In United States - Hadrian North [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 209
United States [Member] | Project In United States - Hadrian North [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,010
United States [Member] | Project In United States - Hadrian North [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,013
United States [Member] | Project in United States - Tip Top [Member]
Exploratory Wells Drilled [Line Items]
Capitalized exploratory well costs	$ 31
United States [Member] | Project in United States - Tip Top [Member] | Minimum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,009
United States [Member] | Project in United States - Tip Top [Member] | Maximum [Member]
Exploratory Wells Drilled [Line Items]
Years wells drilled, period	2,009

Leased Facilities (Narrative)

Leased Facilities (Narrative) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Leased Facilities [Abstract]
Minimum undiscounted lease commitments	$ 4,877
Estimated related rental income from noncancelable subleases	$ 32

Leased Facilities (Leased Facil

Leased Facilities (Leased Facilities) (Details) $ in Millions	Dec. 31, 2015USD ($)
Lease Payments Under Minimum Commitments, 2016	$ 1,653
Lease Payments Under Minimum Commitments, 2017	1,003
Lease Payments Under Minimum Commitments, 2018	555
Lease Payments Under Minimum Commitments, 2019	344
Lease Payments Under Minimum Commitments, 2020	265
Lease Payments Under Minimum Commitments, 2021 and beyond	1,057
Lease Payments Under Minimum Commitments, Total	4,877
Related Sublease Rental Income, 2016	7
Related Sublease Rental Income, 2017	6
Related Sublease Rental Income, 2018	2
Related Sublease Rental Income, 2019	2
Related Sublease Rental Income, 2020	2
Related Sublease Rental Income, 2021 and beyond	13
Related Sublease Rental Income, Total	32
Drilling Rigs and Related Equipment [Member]
Lease Payments Under Minimum Commitments, 2016	827
Lease Payments Under Minimum Commitments, 2017	408
Lease Payments Under Minimum Commitments, 2018	134
Lease Payments Under Minimum Commitments, 2019	89
Lease Payments Under Minimum Commitments, 2020	77
Lease Payments Under Minimum Commitments, 2021 and beyond	86
Lease Payments Under Minimum Commitments, Total	1,621
Other [Member]
Lease Payments Under Minimum Commitments, 2016	826
Lease Payments Under Minimum Commitments, 2017	595
Lease Payments Under Minimum Commitments, 2018	421
Lease Payments Under Minimum Commitments, 2019	255
Lease Payments Under Minimum Commitments, 2020	188
Lease Payments Under Minimum Commitments, 2021 and beyond	971
Lease Payments Under Minimum Commitments, Total	$ 3,256

Leased Facilities (Net Rental C

Leased Facilities (Net Rental Cost) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Rental cost	$ 3,973	$ 4,077	$ 3,841
Less sublease rental income	44	52	44
Net rental cost	3,929	4,025	3,797
Lease Agreements Drilling Rigs And Related Equipment [Member]
Rental cost	1,853	1,763	1,424
Lease Agreements Other [Member]
Rental cost	$ 2,120	$ 2,314	$ 2,417

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Earnings per common share
Net income attributable to ExxonMobil		$ 16,150	$ 32,520	$ 32,580
Weighted average number of common shares outstanding		4,196	4,282	4,419
Earnings per common share (dollars)	[1]	$ 3.85	$ 7.6	$ 7.37
Dividends paid per common share (dollars)		$ 2.88	$ 2.7	$ 2.46
[1]	The earnings per common share and earnings per common share - assuming dilution are the same in each period shown.

Financial Instruments And Der69

Financial Instruments And Derivatives (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Financial Instruments And Derivatives [Line Items]
Estimated fair value of total long-term debt, excluding capitalized lease obligations		$ 18,900	$ 11,700
Recorded book values of total long-term debt, excluding capitalized lease obligations		18,700	11,300
Derivative asset at fair value, net		21	75
Gain (loss) before-tax earnings impact of derivatives		39	110	$ (7)
Additions to long-term debt	$ 8,000	8,028	$ 5,731	$ 345
Level 1 [Member]
Financial Instruments And Derivatives [Line Items]
Estimated fair value of total long-term debt, excluding capitalized lease obligations		18,584
Level 2 [Member]
Financial Instruments And Derivatives [Line Items]
Estimated fair value of total long-term debt, excluding capitalized lease obligations		208
Level 3 [Member]
Financial Instruments And Derivatives [Line Items]
Estimated fair value of total long-term debt, excluding capitalized lease obligations		$ 62

Long-Term Debt (Narrative) (Det

Long-Term Debt (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term debt due in U.S. dollars		$ 19,217
U.S. dollar equivalent at year-end exchange rates of amounts payable in foreign currencies		708
Portion of long-term debt included in current liability		558	$ 770
Long-term debt maturing - 2017		2,959
Long-term debt maturing - 2018		2,967
Long-term debt maturing - 2019		2,374
Long-term debt maturing - 2020		1,602
Additions to long-term debt	$ 8,000	8,028	$ 5,731	$ 345
Long Term Financing [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Unused credit lines		$ 400

Long-Term Debt (Summarized Long

Long-Term Debt (Summarized Long-Term Debt) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Debt Instrument, Unamortized Premium		$ 179	$ 219
Long-term debt		19,925	11,653
Combined Exxon Mobil And Affiliates [Member] | Other U.S. Dollar Obligations [Member]
Other long-term debt	[1]	$ 97	$ 104
Average effective interest rate		3.80%	4.20%
Combined Exxon Mobil And Affiliates [Member] | Other Foreign Currency Obligations [Member]
Other long-term debt		$ 1	$ 9
0.921% Notes Due 2017 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]
Senior notes, noncurrent		$ 1,500	$ 1,500
Interest rate		0.921%	0.921%
Debt maturity		Mar. 15, 2017	Mar. 15, 2017
Floating-Rate Notes Due 2017 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]
Senior notes, noncurrent	[2]	$ 750	$ 750
Debt maturity		Mar. 15, 2017	Mar. 15, 2017
Average effective interest rate		0.30%	0.30%
Floating-Rate Notes Due 2018 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]
Senior notes, noncurrent	[3]	$ 500
Debt maturity		Mar. 1, 2018
Average effective interest rate		0.40%
1.305% Notes Due 2018 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]
Senior notes, noncurrent		$ 1,600
Interest rate		1.305%
Debt maturity		Mar. 6, 2018
1.819% Notes Due 2019 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]
Senior notes, noncurrent		$ 1,750	$ 1,750
Interest rate		1.819%	1.819%
Debt maturity		Mar. 15, 2019	Mar. 15, 2019
Floating-Rate Notes Due 2019 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]
Senior notes, noncurrent	[4]	$ 500	$ 500
Debt maturity		Mar. 15, 2019	Mar. 15, 2019
Average effective interest rate		0.50%	0.40%
1.912% Notes Due 2020 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]
Senior notes, noncurrent		$ 1,500
Interest rate		1.912%
Debt maturity		Mar. 6, 2020
2.397% Notes Due 2022 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]
Senior notes, noncurrent		$ 1,150
Interest rate		2.397%
Debt maturity		Mar. 6, 2022
Floating-Rate Notes Due 2022 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]
Senior notes, noncurrent	[5]	$ 500
Debt maturity		Mar. 6, 2022
Average effective interest rate		0.70%
3.176% Notes Due 2024 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]
Senior notes, noncurrent		$ 1,000	$ 1,000
Interest rate		3.176%	3.176%
Debt maturity		Mar. 15, 2024	Mar. 15, 2024
2.709% Notes Due 2025 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]
Senior notes, noncurrent		$ 1,750
Interest rate		2.709%
Debt maturity		Mar. 6, 2025
3.567% Notes Due 2045 [Member] | Exxon Mobil Corporation [Member] | Other U.S. Dollar Obligations [Member]
Senior notes, noncurrent		$ 1,000
Interest rate		3.567%
Debt maturity		Mar. 6, 2045
5.650% Senior Notes Due 2016 [Member] | XTO Energy Inc. [Member]
Senior notes, noncurrent			$ 207
Interest rate			5.65%
Debt maturity			Apr. 1, 2016
6.250% Senior Notes Due 2017 [Member] | XTO Energy Inc. [Member]
Senior notes, noncurrent		$ 465	$ 477
Interest rate		6.25%	6.25%
Debt maturity		Aug. 1, 2017	Aug. 1, 2017
5.500% Senior Notes Due 2018 [Member] | XTO Energy Inc. [Member]
Senior notes, noncurrent		$ 377	$ 383
Interest rate		5.50%	5.50%
Debt maturity		Jun. 15, 2018	Jun. 15, 2018
6.500% Senior Notes Due 2018 [Member] | XTO Energy Inc. [Member]
Senior notes, noncurrent		$ 463	$ 474
Interest rate		6.50%	6.50%
Debt maturity		Dec. 15, 2018	Dec. 15, 2018
6.100% Senior Notes Due 2036 [Member] | XTO Energy Inc. [Member]
Senior notes, noncurrent		$ 198	$ 199
Interest rate		6.10%	6.10%
Debt maturity		Apr. 1, 2036	Apr. 1, 2036
6.750% Senior Notes Due 2037 [Member] | XTO Energy Inc. [Member]
Senior notes, noncurrent		$ 307	$ 309
Interest rate		6.75%	6.75%
Debt maturity		Aug. 1, 2037	Aug. 1, 2037
6.375% Senior Notes Due 2038 [Member] | XTO Energy Inc. [Member]
Senior notes, noncurrent		$ 235	$ 236
Interest rate		6.375%	6.375%
Debt maturity		Jun. 15, 2038	Jun. 15, 2038
Variable Notes Due 2016-2019 [Member] | Mobil Producing Nigeria Unlimited [Member]
Senior notes, noncurrent	[6]	$ 101	$ 399
Debt Instrument, maturity date range, start		Dec. 15, 2017	Jun. 15, 2016
Debt Instrument, maturity date range, end		Mar. 15, 2019	Mar. 15, 2019
Average effective interest rate		4.60%	4.50%
Variable Notes Due 2016-2020 [Member] | Esso (Thailand) Public Company Ltd. [Member]
Senior notes, noncurrent	[7]	$ 83	$ 121
Debt Instrument, maturity date range, start		Nov. 30, 2017	Nov. 30, 2017
Debt Instrument, maturity date range, end		May 10, 2020	Dec. 31, 2019
Average effective interest rate		2.10%	2.40%
Debentures Due 2021 [Member] | Mobil Corporation [Member]
Other long-term debt		$ 249	$ 249
Interest rate		8.625%	8.625%
Debt maturity		Aug. 15, 2021	Aug. 15, 2021
Industrial Revenue Bonds Due 2017-2051 [Member] | Combined Exxon Mobil And Affiliates [Member]
Other long-term debt	[8]	$ 2,611	$ 2,611
Debt Instrument, maturity date range, start		Apr. 1, 2017	Apr. 1, 2017
Debt Instrument, maturity date range, end		Dec. 1, 2051	Dec. 1, 2051
Average effective interest rate		0.02%	0.03%
Capitalized Lease Obligations [Member] | Combined Exxon Mobil And Affiliates [Member]
Average effective interest rate		9.20%	7.00%
Long-term debt	[9]	$ 1,238	$ 375
[1]	Average effective interest rate of 3.8% in 2015 and 4.2% in 2014.
[2]	Average effective interest rate of 0.3% in 2015 and 0.3% in 2014.
[3]	Average effective interest rate of 0.4% in 2015.
[4]	Average effective interest rate of 0.5% in 2015 and 0.4% in 2014.
[5]	Average effective interest rate of 0.7% in 2015.
[6]	Average effective interest rate of 4.6% in 2015 and 4.5% in 2014.
[7]	Average effective interest rate of 2.1% in 2015 and 2.4% in 2014.
[8]	Average effective interest rate of 0.02% in 2015 and 0.03% in 2014.
[9]	Average imputed interest rate of 9.2% in 2015 and 7.0% in 2014.

Incentive Program (Narrative) (

Incentive Program (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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	100,000,000
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	9,681,000	9,775,000	9,729,000
Unrecognized compensation cost	$ 2,222
Unrecognized compensation cost, weighted-average period of recognition, years	4 years 6 months
Compensation cost charged against income	$ 855	$ 831	$ 854
Income tax benefit recognized in income	78	76	78
Fair value of shares/awards vested	808	946	1,040
Cash payments, vested restricted stock units	$ 64	$ 73	$ 67
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 R

Incentive Program (Summary Of Restricted Stock And Units Outstanding) (Details) shares in Thousands	12 Months Ended
	Dec. 31, 2015$ / sharesshares
Incentive Program [Abstract]
Issued and outstanding at January 1, Restricted stock, Shares | shares	44,439
2014 award issued in 2015, Shares | shares	9,758
Vested, Shares | shares	(9,945)
Forfeited, Shares | shares	(189)
Issued and outstanding at December 31, Restricted stock, Shares | shares	44,063
Issued and outstanding at January 1, Weighted Average Grant-Date Fair Value per Share | $ / shares	$ 81.45
2014 award issued in 2015, Weighted Average Grant-Date Fair Value per Share | $ / shares	95.2
Vested, Weighted Average Grant-Date Fair Value per Share | $ / shares	79.86
Forfeited, Weighted Average Grant-Date Fair Value per Share | $ / shares	82.26
Issued and outstanding at December 31, Weighted Average Grant-Date Fair Value per Share | $ / shares	$ 84.85

Incentive Program (Grant Value

Incentive Program (Grant Value Of Restricted Stock And Units) (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Grant price, per share	$ 81.27	$ 95.2	$ 94.47
Restricted stock and units settled in stock	$ 727	$ 858	$ 843
Units settled in cash	60	73	76
Total value	$ 787	$ 931	$ 919

Litigation And Other Continge75

Litigation And Other Contingencies (Narrative) (Details) - USD ($)	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
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 Continge76

Litigation And Other Contingencies (Schedule Of Guarantees) (Details) $ in Millions	Dec. 31, 2015USD ($)
Loss Contingencies [Line Items]
Guarantees	$ 7,225
Equity Company Obligations [Member]
Loss Contingencies [Line Items]
Guarantees	2,637	[1]
Other Third-Party Obligations [Member]
Loss Contingencies [Line Items]
Guarantees	4,588
Debt-Related Guarantees [Member]
Loss Contingencies [Line Items]
Guarantees	133
Debt-Related Guarantees [Member] | Equity Company Obligations [Member]
Loss Contingencies [Line Items]
Guarantees	98	[1]
Debt-Related Guarantees [Member] | Other Third-Party Obligations [Member]
Loss Contingencies [Line Items]
Guarantees	35
Other Guarantees [Member]
Loss Contingencies [Line Items]
Guarantees	7,092
Other Guarantees [Member] | Equity Company Obligations [Member]
Loss Contingencies [Line Items]
Guarantees	2,539	[1]
Other Guarantees [Member] | Other Third-Party Obligations [Member]
Loss Contingencies [Line Items]
Guarantees	$ 4,553
[1]	ExxonMobil share

Litigation And Other Continge77

Litigation And Other Contingencies (Schedule Of Unconditional Purchase Obligations) (Details) $ in Millions	Dec. 31, 2015USD ($)
Unrecorded Unconditional Purchase Obligation [Line Items]
2,016	$ 133	[1]
2017-2020	493	[1]
2021 and Beyond	310	[1]
Total	936	[1]
Present value of these commitments	792
Undiscounted unconditional purchase obligations	936	[1]
Imputed interest	144
Equity Company Obligations [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Total	411
Undiscounted unconditional purchase obligations	$ 411
[1]	Undiscounted obligations of $936 million mainly pertain to pipeline throughput agreements and include $411 million of obligations to equity companies. The present value of these commitments, which excludes imputed interest of $144 million, totaled $792 million.

Pension And Other Postretirem78

Pension And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate projected in 2017	4.50%
Year that rate reaches ultimate trend rate	2,017
Effect of one-percentage-point increase on service and interest costs	$ 88
Effect of one-percentage-point increase on postretirement benefit obligation	963
Effect of one-percentage-point decrease on service and interest costs	66
Effect of one-percentage-point decrease on postretirement benefit obligation	764
Costs for defined contribution plans	$ 405	$ 393	$ 392
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 Postretirem79

Pension And Other Postretirement Benefits (Benefit Obligations And Plan Assets Associated With Principal Benefit Plans) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Medicare subsidy receipts		$ 15	$ 21
Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate		4.25%	4.00%
Long-term rate of compensation increase		5.75%	5.75%
Benefit obligation at January 1		$ 20,529	$ 17,304
Service cost		864	677	$ 801
Interest cost		785	807	749
Defined benefit plan, actuarial net (gains) losses		(545)	3,192
Amendments, divestments and other			(24)
Benefit obligation at December 31		19,583	20,529	17,304
Accumulated benefit obligation at December 31		$ 15,666	$ 16,385
Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate		3.60%	3.10%
Long-term rate of compensation increase		4.80%	5.30%
Benefit obligation at January 1		$ 30,047	$ 27,357
Service cost		689	590	697
Interest cost		850	1,138	1,076
Defined benefit plan, actuarial net (gains) losses		(1,517)	4,929
Foreign exchange rate changes		(3,242)	(2,540)
Amendments, divestments and other		(423)	(61)
Benefit obligation at December 31		25,117	30,047	27,357
Accumulated benefit obligation at December 31		$ 22,362	$ 26,318
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate		4.25%	4.00%
Long-term rate of compensation increase		5.75%	5.75%
Benefit obligation at January 1		$ 9,436	$ 7,868
Service cost		170	140	176
Interest cost		346	383	352
Defined benefit plan, actuarial net (gains) losses		(617)	1,522
Foreign exchange rate changes		(106)	(48)
Amendments, divestments and other		(465)	96
Benefit obligation at December 31		8,282	9,436	$ 7,868
Benefit Payments For Funded And Unfunded Plans [Member] | Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefits paid	[1]	(2,050)	(1,427)
Benefit Payments For Funded And Unfunded Plans [Member] | Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefits paid	[1]	(1,287)	(1,366)
Benefit Payments For Funded And Unfunded Plans [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefits paid	[1],[2]	$ (482)	$ (525)
[1]	Benefit payments for funded and unfunded plans.
[2]	For 2015 and 2014, other postretirement benefits paid are net of $15 million and $21 million of Medicare subsidy receipts, respectively.

Pension And Other Postretirem80

Pension And Other Postretirement Benefits (Change In Plan Assets Of Pension And Other Postretirement Benefits) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value at January 1		$ 12,915	$ 11,190
Actual return on plan assets		(307)	1,497
Company contribution			1,476
Fair value at December 31		10,985	12,915
Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value at January 1		20,095	19,283
Actual return on plan assets		918	3,153
Foreign exchange rate changes		(2,109)	(1,738)
Company contribution		515	554
Other		(112)	(245)
Fair value at December 31		18,417	20,095
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value at January 1		468	620
Actual return on plan assets			41
Company contribution		42	31
Fair value at December 31		414	468
Benefit Payments For Funded Plans [Member] | Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefits paid	[1]	(1,623)	(1,248)
Benefit Payments For Funded Plans [Member] | Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefits paid	[1]	(890)	(912)
Benefit Payments For Funded Plans [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefits paid	[1]	$ (96)	$ (224)
[1]	Benefit payments for funded plans.

Pension And Other Postretirem81

Pension And Other Postretirement Benefits (Summary Of Assets In Excess Of/(Less Than) Benefit Obligation) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan funded status of plan		$ (5,782)	$ (4,590)
Unfunded plans		(2,816)	(3,024)
Total	[1]	(8,598)	(7,614)
Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan funded status of plan		(588)	(2,113)
Unfunded plans		(6,112)	(7,839)
Total	[1]	$ (6,700)	$ (9,952)
[1]	Fair value of assets less benefit obligation shown on the preceding page.

Pension And Other Postretirem82

Pension And Other Postretirement Benefits (Assets Recorded In Balance Sheet And Other Comprehensive Income) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Postretirement benefits reserves		$ (22,647)	$ (25,802)
Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Balance at December 31	[1]	(8,598)	(7,614)
Current liabilities		(311)	(340)
Postretirement benefits reserves		(8,287)	(7,274)
Total recorded		(8,598)	(7,614)
Net actuarial loss/(gain)		6,138	6,589
Prior service cost		21	27
Total recorded in accumulated other comprehensive income		6,159	6,616
Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Balance at December 31	[1]	(6,700)	(9,952)
Other assets		454	302
Current liabilities		(299)	(325)
Postretirement benefits reserves		(6,855)	(9,929)
Total recorded		(6,700)	(9,952)
Net actuarial loss/(gain)		6,413	9,642
Prior service cost		(83)	429
Total recorded in accumulated other comprehensive income		6,330	10,071
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Balance at December 31	[1]	(7,868)	(8,968)
Current liabilities		(363)	(369)
Postretirement benefits reserves		(7,505)	(8,599)
Total recorded		(7,868)	(8,968)
Net actuarial loss/(gain)		2,171	2,997
Prior service cost		(460)	51
Total recorded in accumulated other comprehensive income		$ 1,711	$ 3,048
[1]	Fair value of assets less benefit obligation shown on the preceding page.

Pension And Other Postretirem83

Pension And Other Postretirement Benefits (Long-Term Rates Of Pension And Other Postretirement Benefits) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Total recorded in other comprehensive income	$ (5,535)	$ 4,619	$ (7,281)
Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.00%	5.00%	4.00%
Long-term rate of return on funded assets	7.00%	7.25%	7.25%
Long-term rate of compensation increase	5.75%	5.75%	5.75%
Service cost	$ 864	$ 677	$ 801
Interest cost	785	807	749
Expected return on plan assets	(830)	(799)	(835)
Amortization of actuarial loss/(gain)	544	409	646
Amortization of prior service cost	6	8	7
Net pension enhancement and curtailment/settlement cost	499	276	723
Net periodic benefit cost	1,868	1,378	2,091
Net actuarial loss/(gain)	592	2,494	(1,302)
Amortization of actuarial (loss)/gain	(1,043)	(685)	(1,369)
Prior service cost/(credit)		(25)
Amortization of prior service (cost)/credit	(6)	(8)	(7)
Total recorded in other comprehensive income	(457)	1,776	(2,678)
Total recorded in net periodic benefit cost and other comprehensive income, before tax	$ 1,411	$ 3,154	$ (587)
Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	3.10%	4.30%	3.80%
Long-term rate of return on funded assets	5.90%	6.30%	6.40%
Long-term rate of compensation increase	5.30%	5.40%	5.50%
Service cost	$ 689	$ 590	$ 697
Interest cost	850	1,138	1,076
Expected return on plan assets	(1,094)	(1,193)	(1,128)
Amortization of actuarial loss/(gain)	730	628	852
Amortization of prior service cost	87	120	117
Net pension enhancement and curtailment/settlement cost	22		22
Net periodic benefit cost	1,284	1,283	1,636
Net actuarial loss/(gain)	(1,375)	2,969	(1,938)
Amortization of actuarial (loss)/gain	(752)	(628)	(874)
Prior service cost/(credit)	(401)	(70)	30
Amortization of prior service (cost)/credit	(87)	(120)	(117)
Foreign exchange rate changes	(1,126)	(688)	(155)
Total recorded in other comprehensive income	(3,741)	1,463	(3,054)
Total recorded in net periodic benefit cost and other comprehensive income, before tax	$ (2,457)	$ 2,746	$ (1,418)
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.00%	5.00%	4.00%
Long-term rate of return on funded assets	7.00%	7.25%	7.25%
Long-term rate of compensation increase	5.75%	5.75%	5.75%
Service cost	$ 170	$ 140	$ 176
Interest cost	346	383	352
Expected return on plan assets	(28)	(37)	(41)
Amortization of actuarial loss/(gain)	206	116	228
Amortization of prior service cost	(24)	14	21
Net periodic benefit cost	670	616	736
Net actuarial loss/(gain)	(589)	1,518	(1,290)
Amortization of actuarial (loss)/gain	(206)	(116)	(228)
Prior service cost/(credit)	(535)
Amortization of prior service (cost)/credit	24	(14)	(21)
Foreign exchange rate changes	(31)	(8)	(10)
Total recorded in other comprehensive income	(1,337)	1,380	(1,549)
Total recorded in net periodic benefit cost and other comprehensive income, before tax	$ (667)	$ 1,996	$ (813)

Pension And Other Postretirem84

Pension And Other Postretirement Benefits (Summary Of The Change In Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Total (charge)/credit to other comprehensive income, before tax	$ 5,535	$ (4,619)	$ 7,281
(Charge)/credit to income tax (see Note 4)	(1,810)	1,549	(2,336)
(Charge)/credit to investment in equity companies	81	(81)	49
(Charge)/credit to other comprehensive income including noncontrolling interests, after tax	3,806	(3,151)	4,994
Charge/(credit) to equity of noncontrolling interests	(202)	85	(279)
Exxon Mobil Corporation Share After Noncontrolling Interest [Member]
Defined Benefit Plan Disclosure [Line Items]
Total change in accumulated other comprehensive income, Postretirement Benefits Reserves Adjustment	3,604	(3,066)	4,715
Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Total (charge)/credit to other comprehensive income, before tax	457	(1,776)	2,678
Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Total (charge)/credit to other comprehensive income, before tax	3,741	(1,463)	3,054
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total (charge)/credit to other comprehensive income, before tax	$ 1,337	$ (1,380)	$ 1,549

Pension And Other Postretirem85

Pension And Other Postretirement Benefits (Fair Value Of Benefit Plan Assets) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Insurance contracts at contract value		$ 15	$ 11
Fair value of plan assets		10,985	12,915	$ 11,190
Pension Benefits - U.S. [Member] | U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1,992	2,331
Pension Benefits - U.S. [Member] | Non-U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1,775	2,144
Pension Benefits - U.S. [Member] | Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		595	562
Pension Benefits - U.S. [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		4,161	4,841
Pension Benefits - U.S. [Member] | Government Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		2,394	2,890
Pension Benefits - U.S. [Member] | Asset-Backed Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		3	5
Pension Benefits - U.S. [Member] | Cash [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		50	131
Pension Benefits - U.S. [Member] | Total At Fair Value [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		10,970	12,904
Pension Benefits - U.S. [Member] | Fair Value Inputs Level 2 [Member] | U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[1]	1,992	2,331
Pension Benefits - U.S. [Member] | Fair Value Inputs Level 2 [Member] | Non-U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[1]	1,775	2,144
Pension Benefits - U.S. [Member] | Fair Value Inputs Level 2 [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[2]	4,161	4,841
Pension Benefits - U.S. [Member] | Fair Value Inputs Level 2 [Member] | Government Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[2]	2,394	2,890
Pension Benefits - U.S. [Member] | Fair Value Inputs Level 2 [Member] | Asset-Backed Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[2]	3	5
Pension Benefits - U.S. [Member] | Fair Value Inputs Level 2 [Member] | Cash [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[3]	50	131
Pension Benefits - U.S. [Member] | Fair Value Inputs Level 2 [Member] | Total At Fair Value [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		10,375	12,342
Pension Benefits - U.S. [Member] | Fair Value Inputs Level 3 [Member] | Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[4]	595	562
Pension Benefits - U.S. [Member] | Fair Value Inputs Level 3 [Member] | Total At Fair Value [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		595	562
Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Insurance contracts at contract value		26	27
Fair value of plan assets		18,417	20,095	$ 19,283
Pension Benefits - Non-U.S. [Member] | U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		3,179	3,284
Pension Benefits - Non-U.S. [Member] | Non-U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		3,608	4,005
Pension Benefits - Non-U.S. [Member] | Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		581	535
Pension Benefits - Non-U.S. [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		2,561	2,686
Pension Benefits - Non-U.S. [Member] | Government Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		8,368	9,299
Pension Benefits - Non-U.S. [Member] | Asset-Backed Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		71	146
Pension Benefits - Non-U.S. [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets			57
Pension Benefits - Non-U.S. [Member] | Cash [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		23	56
Pension Benefits - Non-U.S. [Member] | Total At Fair Value [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		18,391	20,068
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 1 [Member] | Non-U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[5]	179	229
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 1 [Member] | Government Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[6]	243	249
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 1 [Member] | Cash [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		11	25
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 1 [Member] | Total At Fair Value [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		433	503
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 2 [Member] | U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[1]	3,179	3,284
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 2 [Member] | Non-U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[1]	3,429	3,776
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 2 [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[2]	2,561	2,686
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 2 [Member] | Government Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[2]	8,125	9,050
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 2 [Member] | Asset-Backed Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[2]	71	146
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 2 [Member] | Cash [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[7]	12	31
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 2 [Member] | Total At Fair Value [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		17,377	18,973
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 3 [Member] | Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[4]	581	535
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 3 [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[8]		57
Pension Benefits - Non-U.S. [Member] | Fair Value Inputs Level 3 [Member] | Total At Fair Value [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		$ 581	$ 592
[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 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.
[4]	For private equity, fair value is generally established by using revenue or earnings multiples or other relevant market data including Initial Public Offerings.
[5]	For non-U.S. equity securities held in separate accounts, fair value is based on observable quoted prices on active exchanges.
[6]	For corporate and government debt securities that are traded on active exchanges, fair value is based on observable quoted prices.
[7]	For cash balances that are subject to withdrawal penalties or other adjustments, the fair value is treated as a Level 2 input.
[8]	For real estate funds, fair value is based on appraised values developed using comparable market transactions.

Pension And Other Postretirem86

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, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		$ 414	$ 468	$ 620
U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		96	106
Non-U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		67	75
Private Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets			2
Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		79	103
Government Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		170	171
Asset Backed Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1	9
Cash [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1	2
Fair Value Inputs Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		414	466
Fair Value Inputs Level 2 [Member] | U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[1]	96	106
Fair Value Inputs Level 2 [Member] | Non-U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[1]	67	75
Fair Value Inputs Level 2 [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[2]	79	103
Fair Value Inputs Level 2 [Member] | Government Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[2]	170	171
Fair Value Inputs Level 2 [Member] | Asset Backed Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[2]	1	9
Fair Value Inputs Level 2 [Member] | Cash [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		$ 1	2
Fair Value Inputs Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets			2
Fair Value Inputs Level 3 [Member] | Private Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	[3]		$ 2
[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 Postretirem87

Pension And Other Postretirement Benefits (Change In The Fair Value Of Level 3 Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Pension Benefits - U.S. [Member] | Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value at January 1	$ 562	$ 523
Net realized gains/(losses)	1	2
Net unrealized gains/(losses)	106	89
Net purchases/(sales)	(74)	(52)
Fair value at December 31	595	562
Pension Benefits - Non-U.S. [Member] | Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value at January 1	535	502
Net realized gains/(losses)	26	23
Net unrealized gains/(losses)	64	31
Net purchases/(sales)	(44)	(21)
Fair value at December 31	581	535
Pension Benefits - Non-U.S. [Member] | Real Estate Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value at January 1	57	136
Net realized gains/(losses)	(5)	(17)
Net unrealized gains/(losses)		8
Net purchases/(sales)	(52)	(70)
Fair value at December 31		57
Other Postretirement Benefits [Member] | Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value at January 1	2	9
Net purchases/(sales)	$ (2)	(7)
Fair value at December 31		$ 2

Pension And Other Postretirem88

Pension And Other Postretirement Benefits (Pension Plans With Accumulated Benefit Obligation In Excess Of Plan Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Funded Pension Plans [Member] | Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	$ 16,767	$ 17,505
Accumulated benefit obligation	13,913	14,493
Fair value of plan assets	10,985	12,915
Funded Pension Plans [Member] | Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	1,827	5,031
Accumulated benefit obligation	1,373	4,590
Fair value of plan assets	1,299	3,890
Unfunded Pension Plans [Member] | Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	2,816	3,024
Accumulated benefit obligation	1,753	1,892
Unfunded Pension Plans [Member] | Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	6,112	7,839
Accumulated benefit obligation	$ 5,290	$ 6,573

Pension And Other Postretirem89

Pension And Other Postretirement Benefits (Estimated Amortization) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss/(gain)	$ 930	[1]
Prior service cost	6	[2]
Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss/(gain)	543	[1]
Prior service cost	55	[2]
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss/(gain)	152	[1]
Prior service cost	$ (30)	[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 Postretirem90

Pension And Other Postretirement Benefits (Expected Contribution Pension Benefits And Other Postretirement Benefits) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Pension Benefits - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions expected in 2016	$ 2,000
Benefits payments expected in 2016	1,548
Benefits payments expected in 2017	1,491
Benefits payments expected in 2018	1,411
Benefits payments expected in 2019	1,382
Benefits payments expected in 2020	1,342
Benefits payments expected in 2021-2025	6,594
Pension Benefits - Non-U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions expected in 2016	525
Benefits payments expected in 2016	1,145
Benefits payments expected in 2017	1,128
Benefits payments expected in 2018	1,178
Benefits payments expected in 2019	1,193
Benefits payments expected in 2020	1,227
Benefits payments expected in 2021-2025	6,359
Gross Other Post Retirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefits payments expected in 2016	457
Benefits payments expected in 2017	470
Benefits payments expected in 2018	481
Benefits payments expected in 2019	490
Benefits payments expected in 2020	497
Benefits payments expected in 2021-2025	2,518
Other Postretirement Benefits Medicare Subsidy Receipt [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefits payments expected in 2016	24
Benefits payments expected in 2017	25
Benefits payments expected in 2018	26
Benefits payments expected in 2019	28
Benefits payments expected in 2020	29
Benefit payments expected in 2021-2025	$ 170

Disclosures About Segments An91

Disclosures About Segments And Related Information (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Disclosures About Segments And Related Information [Abstract]
Non-debt-related interest expense	$ 100	$ 129	$ (123)

Disclosures About Segments An92

Disclosures About Segments And Related Information (Schedule Of Segments And Related Information) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Earnings after income tax		$ 16,150	$ 32,520	$ 32,580
Earnings of equity companies included above		7,644	13,323	13,927
Sales and other operating revenue	[1],[2]	259,488	394,105	420,836
Depreciation and depletion expense		18,048	17,297	17,182
Interest revenue		46	75	87
Interest expense		311	286	9
Income taxes		5,415	18,015	24,263
Additions to property, plant and equipment		27,475	34,256	37,741
Investments in equity companies		20,337	20,017	19,619
Total assets		336,758	349,493	346,808
U.S. [Member]
Income taxes		(1,140)	1,862	1,391
Non-U.S. [Member]
Income taxes		6,555	16,153	22,872
Upstream [Member] | U.S. [Member]
Earnings after income tax		(1,079)	5,197	4,191
Earnings of equity companies included above		226	1,235	1,576
Sales and other operating revenue	[2]	8,241	14,826	13,712
Intersegment revenue		4,344	7,723	8,343
Depreciation and depletion expense		5,301	5,139	5,170
Interest expense		26	40	30
Income taxes		(879)	1,300	2,197
Additions to property, plant and equipment		6,915	9,098	7,480
Investments in equity companies		5,160	5,089	4,975
Total assets		93,648	92,555	88,698
Upstream [Member] | Non-U.S. [Member]
Earnings after income tax		8,180	22,351	22,650
Earnings of equity companies included above		5,831	10,859	11,627
Sales and other operating revenue	[2]	15,812	22,336	25,349
Intersegment revenue		20,839	38,846	45,761
Depreciation and depletion expense		9,227	8,523	8,277
Interest expense		27	17	26
Income taxes		4,703	15,165	21,554
Additions to property, plant and equipment		14,561	19,225	26,075
Investments in equity companies		10,980	10,877	9,740
Total assets		155,316	161,033	157,465
Downstream [Member] | U.S. [Member]
Earnings after income tax		1,901	1,618	2,199
Earnings of equity companies included above		170	29	(460)
Sales and other operating revenue	[2]	73,063	118,771	123,802
Intersegment revenue		12,440	17,281	20,781
Depreciation and depletion expense		664	654	633
Interest expense		8	6	7
Income taxes		866	610	721
Additions to property, plant and equipment		916	1,050	616
Investments in equity companies		95	69	62
Total assets		16,498	18,371	19,261
Downstream [Member] | Non-U.S. [Member]
Earnings after income tax		4,656	1,427	1,250
Earnings of equity companies included above		444	82	22
Sales and other operating revenue	[2]	134,230	199,976	218,904
Intersegment revenue		22,166	44,231	52,624
Depreciation and depletion expense		1,003	1,228	1,390
Interest expense		4	4	8
Income taxes		1,325	968	481
Additions to property, plant and equipment		1,477	1,356	1,072
Investments in equity companies		1,179	1,006	1,749
Total assets		29,808	33,299	40,661
Chemical [Member] | U.S. [Member]
Earnings after income tax		2,386	2,804	2,755
Earnings of equity companies included above		144	186	189
Sales and other operating revenue	[2]	10,880	15,115	15,295
Intersegment revenue		7,442	10,117	11,993
Depreciation and depletion expense		375	370	378
Interest expense				1
Income taxes		646	1,032	989
Additions to property, plant and equipment		1,865	1,564	840
Investments in equity companies		125	258	217
Total assets		10,174	8,798	7,816
Chemical [Member] | Non-U.S. [Member]
Earnings after income tax		2,032	1,511	1,073
Earnings of equity companies included above		1,235	1,377	1,422
Sales and other operating revenue	[2]	17,254	23,063	23,753
Intersegment revenue		5,168	8,098	8,232
Depreciation and depletion expense		654	645	632
Interest expense		1
Income taxes		633	358	363
Additions to property, plant and equipment		629	564	272
Investments in equity companies		3,025	3,026	3,103
Total assets		18,236	18,449	19,659
Corporate And Financing [Member]
Earnings after income tax		(1,926)	(2,388)	(1,538)
Earnings of equity companies included above		(406)	(445)	(449)
Sales and other operating revenue	[2]	8	18	21
Intersegment revenue		274	274	285
Depreciation and depletion expense		824	738	702
Interest revenue		46	75	87
Interest expense		245	219	(63)
Income taxes		(1,879)	(1,418)	(2,042)
Additions to property, plant and equipment		1,112	1,399	1,386
Investments in equity companies		(227)	(308)	(227)
Total assets		$ 13,078	$ 16,988	$ 13,248
[1]	Sales and other operating revenue includes sales-based taxes of $22,678 million for 2015, $29,342 million for 2014 and $30,589 million for 2013.
[2]	Sales and other operating revenue includes sales-based taxes of $22,678 million for 2015, $29,342 million for 2014 and $30,589 million for 2013. See Note 1, Summary of Accounting Policies.

Disclosures About Segments An93

Disclosures About Segments And Related Information (Schedule Of Geographic Sales And Other Operating Revenue) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Revenue Reconciling Item [Line Items]
Sales and other operating revenue	[1]	$ 259,488	$ 394,105	$ 420,836
Sales-based taxes	[2]	22,678	29,342	30,589
U.S. [Member]
Segment Reporting Revenue Reconciling Item [Line Items]
Sales and other operating revenue	[1]	92,184	148,713	152,820
Sales-based taxes		6,402	6,310	5,992
Non-U.S. [Member]
Segment Reporting Revenue Reconciling Item [Line Items]
Sales and other operating revenue	[1]	167,304	245,392	268,016
Sales-based taxes		16,276	23,032	24,597
United Kingdom [Member]
Segment Reporting Revenue Reconciling Item [Line Items]
Sales and other operating revenue	[1]	23,651	31,346	34,061
Canada [Member]
Segment Reporting Revenue Reconciling Item [Line Items]
Sales and other operating revenue	[1]	22,876	36,072	35,924
Italy [Member]
Segment Reporting Revenue Reconciling Item [Line Items]
Sales and other operating revenue	[1]	13,795	18,880	19,273
Belgium [Member]
Segment Reporting Revenue Reconciling Item [Line Items]
Sales and other operating revenue	[1]	13,154	20,953	20,973
France [Member]
Segment Reporting Revenue Reconciling Item [Line Items]
Sales and other operating revenue	[1]	11,808	17,639	18,444
Singapore [Member]
Segment Reporting Revenue Reconciling Item [Line Items]
Sales and other operating revenue	[1]	10,790	15,407	15,623
Germany [Member]
Segment Reporting Revenue Reconciling Item [Line Items]
Sales and other operating revenue	[1]	$ 10,045	$ 14,816	$ 15,701
[1]	Sales and other operating revenue includes sales-based taxes of $22,678 million for 2015, $29,342 million for 2014 and $30,589 million for 2013. See Note 1, Summary of Accounting Policies.
[2]	Sales and other operating revenue includes sales-based taxes of $22,678 million for 2015, $29,342 million for 2014 and $30,589 million for 2013.

Disclosures About Segments An94

Disclosures About Segments And Related Information (Schedule Of Long-Lived Assets By Geographic Regions) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Long-lived assets	$ 251,605	$ 252,668	$ 243,650
U.S. [Member]
Long-lived assets	107,039	104,000	98,271
Non-U.S. [Member]
Long-lived assets	144,566	148,668	145,379
Canada [Member]
Long-lived assets	39,775	43,858	41,522
Australia [Member]
Long-lived assets	15,894	15,328	14,258
Nigeria [Member]
Long-lived assets	12,222	12,265	12,343
Kazakhstan [Member]
Long-lived assets	9,705	9,138	8,530
Singapore [Member]
Long-lived assets	9,681	9,620	9,570
Angola [Member]
Long-lived assets	8,777	9,057	8,262
Papua New Guinea [Member]
Long-lived assets	$ 5,985	$ 6,099	$ 5,768

Income, Sales-Based And Other95

Income, Sales-Based And Other Taxes (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income, Sales-Based And Other Taxes [Abstract]
Net deferred income tax expense (credits)/charges for tax rate and law changes	$ 177,000,000	$ (40,000,000)	$ (310,000,000)
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	20.00%
Credit of net interest expense on income tax reserves			$ 207,000,000
Interest expense on income tax reserves	$ 39,000,000	$ 42,000,000
Interest payable on income tax reserves	223,000,000	205,000,000
Asset valuation allowances	1,730,000,000	$ 2,570,000,000
Valuation allowance change from 2014 to 2015	(840,000,000)
Change in net provisions [Member]
Valuation allowance change from 2014 to 2015	(681,000,000)
Effects of foreign currency translation [Member]
Valuation allowance change from 2014 to 2015	$ (159,000,000)

Income, Sales-Based And Other96

Income, Sales-Based And Other Taxes (Schedule Of Income, Sales-Based And Other Taxes) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Income, Sales-Based and Other Taxes [Line Items]
Current		$ 7,126	$ 16,211		$ 23,188
Deferred - net		(1,737)	2,298		641
U.S. tax on non-U.S. operations		38	5		37
Total federal and non-U.S.		5,427	18,514		23,866
State		(12)	(499)	[1]	397
Total income tax expense		5,415	18,015		24,263
Sales-based taxes	[2]	22,678	29,342		30,589
Other taxes and duties		27,265	32,286		33,230
Other taxes and duties included in production and manufacturing expenses		1,985	2,633		2,500
Other taxes and duties included in SG&A expenses		540	596		666
Total other taxes and duties		29,790	35,515		36,396
Total		57,883	82,872		91,248
U.S. [Member]
Income, Sales-Based and Other Taxes [Line Items]
Current			1,456		1,073
Deferred - net		(1,166)	900		(116)
U.S. tax on non-U.S. operations		38	5		37
Total federal and non-U.S.		(1,128)	2,361		994
State		(12)	(499)	[1]	397
Total income tax expense		(1,140)	1,862		1,391
Sales-based taxes		6,402	6,310		5,992
Other taxes and duties		162	378		955
Other taxes and duties included in production and manufacturing expenses		1,157	1,454		1,318
Other taxes and duties included in SG&A expenses		150	155		150
Total other taxes and duties		1,469	1,987		2,423
Total		6,731	10,159		9,806
U.S. [Member] | State Tax Adjustment [Member]
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		7,126	14,755		22,115
Deferred - net		(571)	1,398		757
Total federal and non-U.S.		6,555	16,153		22,872
Total income tax expense		6,555	16,153		22,872
Sales-based taxes		16,276	23,032		24,597
Other taxes and duties		27,103	31,908		32,275
Other taxes and duties included in production and manufacturing expenses		828	1,179		1,182
Other taxes and duties included in SG&A expenses		390	441		516
Total other taxes and duties		28,321	33,528		33,973
Total		$ 51,152	$ 72,713		$ 81,442
[1]	In 2014, state taxes included a favorable adjustment of deferred taxes of approximately $830 million.
[2]	Sales and other operating revenue includes sales-based taxes of $22,678 million for 2015, $29,342 million for 2014 and $30,589 million for 2013.

Income, Sales-Based And Other97

Income, Sales-Based And Other Taxes (Reconciliation Between Income Tax Expense And Theoretical U.S. Tax) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income, Sales-Based And Other Taxes [Abstract]
United States income before income taxes	$ 147	$ 9,080	$ 9,746
Non-U.S. income before income taxes	21,819	42,550	47,965
Income before income taxes	21,966	51,630	57,711
Theoretical tax	7,688	18,071	20,199
Effect of equity method of accounting	(2,675)	(4,663)	(4,874)
Non-U.S. taxes in excess of theoretical U.S. tax	1,415	5,442	10,528
U.S. tax on non-U.S. operations	38	5	37
State taxes, net of federal tax benefit	(8)	(324)	258
Other	(1,043)	(516)	(1,885)
Total income tax expense	5,415	18,015	24,263
ExxonMobil share of equity company income taxes	3,011	5,678	6,061
Total income taxes	8,426	23,693	30,324
Net income including noncontrolling interests	16,551	33,615	33,448
Total income before taxes	$ 24,977	$ 57,308	$ 63,772
Effective income tax rate	34.00%	41.00%	48.00%

Income, Sales-Based And Other98

Income, Sales-Based And Other Taxes (Deferred Income Taxes Assets And Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Income, Sales-Based And Other Taxes [Abstract]
Property, plant and equipment	$ 49,409	$ 51,643
Other liabilities	4,613	4,359
Total deferred tax liabilities	54,022	56,002
Pension and other postretirement benefits	(6,286)	(8,140)
Asset retirement obligations	(6,277)	(6,162)
Tax loss carryforwards	(4,983)	(4,099)
Other assets	(5,592)	(6,446)
Total deferred tax assets	(23,138)	(24,847)
Asset valuation allowances	1,730	2,570
Net deferred tax liabilities	$ 32,614	$ 33,725

Income, Sales-Based And Other99

Income, Sales-Based And Other Taxes (Deferred Income Tax (Assets) And Liabilities By Balance Sheet Classification) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Income, Sales-Based And Other Taxes [Abstract]
Other current assets	$ (1,329)	$ (2,001)
Other assets, including intangibles, net	(3,421)	(3,955)
Accounts payable and accrued liabilities	546	451
Deferred income tax liabilities	36,818	39,230
Net deferred tax liabilities	$ 32,614	$ 33,725

Income, Sales-Based And Othe100

Income, Sales-Based And Other Taxes (Unrecognized Tax Benefits) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income, Sales-Based And Other Taxes [Abstract]
Balance at January 1	$ 8,986	$ 7,838	$ 7,663
Additions based on current year's tax positions	903	1,454	1,460
Additions for prior years' tax positions	496	448	464
Reductions for prior years' tax positions	(190)	(532)	(249)
Reductions due to lapse of the statute of limitations	(4)	(117)	(588)
Settlements with tax authorities	(725)	(43)	(849)
Foreign exchange effects/other	(70)	(62)	(63)
Balance at December 31	$ 9,396	$ 8,986	$ 7,838

Income, Sales-Based And Othe101

Income, Sales-Based And Other Taxes (Remaining Tax Years Subject To Examination By Major Tax Jurisdiction) (Details)	12 Months Ended
	Dec. 31, 2015
Abu Dhabi [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,015
Abu Dhabi [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,012
Angola [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,015
Angola [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,009
Australia First Range [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,005
Australia First Range [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,005
Australia Second Range [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,015
Australia Second Range [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,008
Canada [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,015
Canada [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,008
Equatorial Guinea [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,015
Equatorial Guinea [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,007
Malaysia [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,015
Malaysia [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,009
Nigeria [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,015
Nigeria [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,005
Norway [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,015
Norway [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,007
Qatar [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,015
Qatar [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,009
Russia [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,015
Russia [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,012
United Kingdom [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,015
United Kingdom [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,011
United States [Member] | Maximum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,015
United States [Member] | Minimum [Member]
Income, Sales-Based and Other Taxes [Line Items]
Open tax years by major tax jurisdiction	2,006