Chevron (CVX) 10-K 25 Feb 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2015	Feb. 15, 2016	Jun. 30, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	CHEVRON CORP
Entity Central Index Key	93,410
Document Type	10-K
Document Period End Date	Dec. 31, 2015
Amendment Flag	false
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$ 181,530,939,081
Entity Common Stock, Shares Outstanding		1,883,156,295

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 revenues	[1]	$ 129,925	$ 200,494	$ 220,156
Income from equity affiliates		4,684	7,098	7,527
Other income		3,868	4,378	1,165
Total Revenues and Other Income		138,477	211,970	228,848
Costs and Other Deductions
Purchased crude oil and products		69,751	119,671	134,696
Operating expenses		23,034	25,285	24,627
Selling, general and administrative expenses		4,443	4,494	4,510
Exploration expenses		3,340	1,985	1,861
Depreciation, depletion and amortization	[2],[3]	21,037	16,793	14,186
Taxes other than on income	[1]	12,030	12,540	13,063
Total Costs and Other Deductions		133,635	180,768	192,943
Income Before Income Tax Expense		4,842	31,202	35,905
Income Tax Expense		132	11,892	14,308
Net Income		4,710	19,310	21,597
Less: Net income attributable to noncontrolling interests		123	69	174
Net Income Attributable to Chevron Corporation	[4]	$ 4,587	$ 19,241	$ 21,423
Net Income Attributable to Chevron Corporation
– Basic (per share)		$ 2.46	$ 10.21	$ 11.18
– Diluted (per share)		$ 2.45	$ 10.14	$ 11.09
[1]	Includes excise, value-added and similar taxes. $7,359; $8,186; $8,492.
[2]	Depreciation expense includes accretion expense of $715, $882 and $627 in 2015, 2014 and 2013, respectively
[3]	Other than the United States, Australia and Nigeria, no other country accounted for 10 percent or more of the company’s net properties, plant and equipment (PP&E) in 2015. Australia had $49,205, $41,012 and $31,464 in 2015, 2014, and 2013, respectively. Nigeria had PP&E of $18,773, $19,214 and $18,429 for 2015, 2014 and 2013, respectively.
[4]	There was no effect of dividend equivalents paid on stock units or dilutive impact of employee stock-based awards on earnings.

Consolidated Statement of Inco3

Consolidated Statement of Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Statement [Abstract]
Includes excise, value-added and similar taxes	$ 7,359	$ 8,186	$ 8,492

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Statement of Comprehensive Income [Abstract]
Net Income	$ 4,710	$ 19,310	$ 21,597
Currency translation adjustment
Unrealized net change arising during period	(44)	(73)	42
Unrealized holding loss on securities
Net loss arising during period	(21)	(2)	(7)
Derivatives
Net derivatives loss on hedge transactions	0	(66)	(111)
Reclassification to net income of net realized (gain) loss	0	(17)	(1)
Income taxes on derivatives transactions	0	29	39
Total	0	(54)	(73)
Actuarial gain (loss)
Amortization to net income of net actuarial loss and settlements	794	757	866
Actuarial gain (loss) arising during period	109	(2,730)	3,379
Prior service credits (cost)
Amortization to net income of net prior service costs (credits) and curtailments	30	26	(27)
Prior service credits (costs) arising during period	6	(6)	60
Defined benefit plans sponsored by equity affiliates	30	(99)	164
Income taxes on defined benefit plans	(336)	901	(1,614)
Total	633	(1,151)	2,828
Other Comprehensive Gain (Loss), Net of Tax	568	(1,280)	2,790
Comprehensive Income	5,278	18,030	24,387
Comprehensive income attributable to noncontrolling interests	(123)	(69)	(174)
Comprehensive Income Attributable to Chevron Corporation	$ 5,155	$ 17,961	$ 24,213

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Assets
Cash and cash equivalents		$ 11,022	$ 12,785
Time deposits		0	8
Marketable securities		310	422
Accounts and notes receivable (less allowance: 2015 - $313; 2014 - $59)		12,860	16,736
Inventories:
Crude oil and petroleum products		3,535	3,854
Chemicals		490	467
Materials, supplies and other		2,309	2,184
Total inventories		6,334	6,505
Prepaid expenses and other current assets		4,821	5,776
Total Current Assets		35,347	42,232
Long-term receivables, net		2,412	2,817
Investments and advances	[1]	27,110	26,912
Properties, plant and equipment, at cost	[2]	340,277	327,289
Less: Accumulated depreciation, depletion and amortization		151,881	144,116
Properties, plant and equipment, net	[2]	188,396	183,173
Deferred charges and other assets		6,801	6,299
Goodwill		4,588	4,593	[3]
Assets held for sale		1,449	0
Total Assets		266,103	266,026	[3]
Liabilities and Equity
Short-term debt		4,928	3,790
Accounts payable		13,516	19,000
Accrued liabilities		4,833	5,328
Federal and other taxes on income		2,069	2,575
Other taxes payable		1,118	1,233
Total Current Liabilities		26,464	31,926
Long-term debt		33,584	23,960
Capital lease obligations		80	68
Deferred credits and other noncurrent obligations		23,465	23,549
Noncurrent deferred income taxes		20,689	21,920
Noncurrent employee benefit plans		7,935	8,412
Total Liabilities		112,217	109,835
Preferred stock (authorized 100,000,000 shares; $1.00 par value; none issued)		0	0
Common stock (authorized 6,000,000,000 shares; $0.75 par value; 2,442,676,580 shares issued at December 31, 2015 and 2014)		1,832	1,832
Capital in excess of par value		16,330	16,041
Retained earnings		181,578	184,987
Accumulated other comprehensive loss		(4,291)	(4,859)
Deferred compensation and benefit plan trust		(240)	(240)
Treasury stock, at cost (2015 - 559,862,580 shares; 2014 - 563,027,772 shares)		(42,493)	(42,733)
Total Chevron Corporation Stockholders' Equity		152,716	155,028
Noncontrolling interests		1,170	1,163
Total Equity		153,886	156,191
Total Liabilities and Equity		$ 266,103	$ 266,026
[1]	2014 conformed to 2015 presentation
[2]	Other than the United States, Australia and Nigeria, no other country accounted for 10 percent or more of the company’s net properties, plant and equipment (PP&E) in 2015. Australia had $49,205, $41,012 and $31,464 in 2015, 2014, and 2013, respectively. Nigeria had PP&E of $18,773, $19,214 and $18,429 for 2015, 2014 and 2013, respectively.
[3]	2014 conformed to 2015 presentation

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Allowance for accounts and notes receivable, current	$ 313	$ 59
Preferred stock, par value (usd per share)	$ 1	$ 1
Preferred stock, shares authorized	100,000,000	100,000,000
Preferred stock, shares issued	0	0
Common stock, par value (usd per share)	$ 0.75	$ 0.75
Common stock, shares authorized	6,000,000,000	6,000,000,000
Common stock, shares issued	2,442,676,580	2,442,676,580
Treasury stock, shares	559,862,580	563,027,772

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating Activities
Net Income		$ 4,710	$ 19,310	$ 21,597
Adjustments
Depreciation, depletion and amortization	[1],[2]	21,037	16,793	14,186
Dry hole expense		2,309	875	683
Distributions less than income from equity affiliates		(760)	(2,202)	(1,178)
Net before-tax gains on asset retirements and sales		(3,215)	(3,540)	(639)
Net foreign currency effects		(82)	(277)	(103)
Deferred income tax provision		(1,861)	1,572	1,876
Net increase in operating working capital		(1,979)	(540)	(1,331)
(Increase) decrease in long-term receivables		(59)	(9)	183
Decrease (increase) in other deferred charges		25	263	(321)
Cash contributions to employee pension plans		(868)	(392)	(1,194)
Other		199	(378)	1,243
Net Cash Provided by Operating Activities		19,456	31,475	35,002
Investing Activities
Capital expenditures		(29,504)	(35,407)	(37,985)
Proceeds and deposits related to asset sales		5,739	5,729	1,143
Net maturities of time deposits		8	0	700
Net sales (purchases) of marketable securities		122	(148)	3
Net (borrowing) repayment of loans by equity affiliates		(217)	140	314
Net sales (purchases) of other short-term investments		44	(207)	216
Net Cash Used for Investing Activities		(23,808)	(29,893)	(35,609)
Financing Activities
Net (repayments) borrowings of short-term obligations		(335)	3,431	2,378
Proceeds from issuances of long-term debt		11,091	4,000	6,000
Repayments of long-term debt and other financing obligations		(32)	(43)	(132)
Cash dividends - common stock		(7,992)	(7,928)	(7,474)
Distributions to noncontrolling interests		(128)	(47)	(99)
Net sales (purchases) of treasury shares		211	(4,412)	(4,494)
Net Cash Provided by (Used for) Financing Activities		2,815	(4,999)	(3,821)
Effect of Exchange Rate Changes on Cash and Cash Equivalents		(226)	(43)	(266)
Net Change in Cash and Cash Equivalents		(1,763)	(3,460)	(4,694)
Cash and Cash Equivalents at January 1		12,785	16,245	20,939
Cash and Cash Equivalents at December 31		$ 11,022	$ 12,785	$ 16,245
[1]	Depreciation expense includes accretion expense of $715, $882 and $627 in 2015, 2014 and 2013, respectively
[2]	Other than the United States, Australia and Nigeria, no other country accounted for 10 percent or more of the company’s net properties, plant and equipment (PP&E) in 2015. Australia had $49,205, $41,012 and $31,464 in 2015, 2014, and 2013, respectively. Nigeria had PP&E of $18,773, $19,214 and $18,429 for 2015, 2014 and 2013, respectively.

Consolidated Statement of Equit

Consolidated Statement of Equity - USD ($) shares in Thousands, $ in Millions	Total		Parent [Member]	Preferred Stock	Common Stock	Capital in Excess of Par	Retained Earnings	Accumulated Other Comprehensive Loss	Currency translation adjustment	Unrealized net holding (loss) gain on securities	Net derivatives (loss) gain on hedge transactions	Pension and other postretirement benefit plans	Deferred Compensation and Benefit Plan Trust	Deferred Compensation	Benefit Plan Trust (Common Stock)	Treasury Stock at Cost	Noncontrolling Interests
Balance at January 1, shares at Dec. 31, 2012																495,979
Balance at January 1 at Dec. 31, 2012						$ 15,497	$ 159,730		$ (65)	$ 1	$ 125	$ (6,430)		$ (42)		$ (33,884)	$ 1,308
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to Chevron Corporation	$ 21,423	[1]					21,423
Cash dividends on common stock							(7,474)
Stock dividends							(3)
Tax (charge) benefit from dividends paid on unallocated ESOP shares and other							1
Change during year	2,790								42	(7)	(73)	2,828
Net reduction of ESOP debt and other														42
Purchases, shares																41,676
Purchases						216										$ (5,004)
Issuances - mainly employee benefit plans, shares																(8,581)
Issuances - mainly employee benefit plans																$ 598
Balance at December 31, shares at Dec. 31, 2013				0	2,442,677								14,168		14,168	529,074
Balance at December 31 at Dec. 31, 2013	150,427		$ 149,113	$ 0	$ 1,832	15,713	173,677	$ (3,579)	(23)	(6)	52	(3,602)	$ (240)	0	$ (240)	$ (38,290)	1,314
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to Chevron Corporation	19,241	[1]					19,241
Cash dividends on common stock							(7,928)
Stock dividends							(3)
Tax (charge) benefit from dividends paid on unallocated ESOP shares and other							0
Change during year	(1,280)								(73)	(2)	(54)	(1,151)
Net reduction of ESOP debt and other														0
Purchases, shares																41,592
Purchases						328										$ (5,006)
Issuances - mainly employee benefit plans, shares																(7,638)
Issuances - mainly employee benefit plans																$ 563
Balance at December 31, shares at Dec. 31, 2014				0	2,442,677								14,168		14,168	563,028
Balance at December 31 at Dec. 31, 2014	156,191		155,028	$ 0	$ 1,832	16,041	184,987	(4,859)	(96)	(8)	(2)	(4,753)	$ (240)	0	$ (240)	$ (42,733)	1,163
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to Chevron Corporation	4,587	[1]					4,587
Cash dividends on common stock							(7,992)
Stock dividends							(3)
Tax (charge) benefit from dividends paid on unallocated ESOP shares and other							(1)
Change during year	568								(44)	(21)	0	633
Net reduction of ESOP debt and other														0
Purchases, shares																15
Purchases						289										$ (2)
Issuances - mainly employee benefit plans, shares																(3,180)
Issuances - mainly employee benefit plans																$ 242
Balance at December 31, shares at Dec. 31, 2015				0	2,442,677								14,168		14,168	559,863
Balance at December 31 at Dec. 31, 2015	$ 153,886		$ 152,716	$ 0	$ 1,832	$ 16,330	$ 181,578	$ (4,291)	$ (140)	$ (29)	$ (2)	$ (4,120)	$ (240)	$ 0	$ (240)	$ (42,493)	$ 1,170
[1]	There was no effect of dividend equivalents paid on stock units or dilutive impact of employee stock-based awards on earnings.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies General The company’s Consolidated Financial Statements are prepared in accordance with accounting principles generally accepted in the United States of America. These require the use of estimates and assumptions that affect the assets, liabilities, revenues and expenses reported in the financial statements, as well as amounts included in the notes thereto, including discussion and disclosure of contingent liabilities. Although the company uses its best estimates and judgments, actual results could differ from these estimates as future confirming events occur. Subsidiary and Affiliated Companies The Consolidated Financial Statements include the accounts of controlled subsidiary companies more than 50 percent-owned and any variable-interest entities in which the company is the primary beneficiary. Undivided interests in oil and gas joint ventures and certain other assets are consolidated on a proportionate basis. Investments in and advances to affiliates in which the company has a substantial ownership interest of approximately 20 percent to 50 percent, or for which the company exercises significant influence but not control over policy decisions, are accounted for by the equity method. As part of that accounting, the company recognizes gains and losses that arise from the issuance of stock by an affiliate that results in changes in the company’s proportionate share of the dollar amount of the affiliate’s equity currently in income. Investments in affiliates are assessed for possible impairment when events indicate that the fair value of the investment may be below the company’s carrying value. When such a condition is deemed to be other than temporary, the carrying value of the investment is written down to its fair value, and the amount of the write-down is included in net income. In making the determination as to whether a decline is other than temporary, the company considers such factors as the duration and extent of the decline, the investee’s financial performance, and the company’s ability and intention to retain its investment for a period that will be sufficient to allow for any anticipated recovery in the investment’s market value. The new cost basis of investments in these equity investees is not changed for subsequent recoveries in fair value. 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 various factors giving rise to the difference. When appropriate, the company’s share of the affiliate’s reported earnings is adjusted quarterly to reflect the difference between these allocated values and the affiliate’s historical book values. Fair Value Measurements The three levels of the fair value hierarchy of inputs the company uses to measure the fair value of an asset or a liability are as follows. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Level 3 inputs are inputs that are not observable in the market. Derivatives The majority of the company’s activity in derivative commodity instruments is intended to manage the financial risk posed by physical transactions. For some of this derivative activity, generally limited to large, discrete or infrequently occurring transactions, the company may elect to apply fair value or cash flow hedge accounting. For other similar derivative instruments, generally because of the short-term nature of the contracts or their limited use, the company does not apply hedge accounting, and changes in the fair value of those contracts are reflected in current income. For the company’s commodity trading activity, gains and losses from derivative instruments are reported in current income. The company may enter into interest rate swaps from time to time as part of its overall strategy to manage the interest rate risk on its debt. Interest rate swaps related to a portion of the company’s fixed-rate debt, if any, may be accounted for as fair value hedges. Interest rate swaps related to floating-rate debt, if any, are recorded at fair value on the balance sheet with resulting gains and losses reflected in income. Where Chevron is a party to master netting arrangements, fair value receivable and payable amounts recognized for derivative instruments executed with the same counterparty are generally offset on the balance sheet. Short-Term Investments All short-term investments are classified as available for sale and are in highly liquid debt securities. Those investments that are part of the company’s cash management portfolio and have original maturities of three months or less are reported as “Cash equivalents.” Bank time deposits with maturities greater than 90 days are reported as “Time deposits.” The balance of short-term investments is reported as “Marketable securities” and is marked-to-market, with any unrealized gains or losses included in “Other comprehensive income.” Inventories Crude oil, petroleum products and chemicals inventories are generally stated at cost, using a last-in, first-out method. In the aggregate, these costs are below market. “Materials, supplies and other” inventories generally are stated at average cost. Properties, Plant and Equipment The successful efforts method is used for crude oil and natural gas exploration and production activities. All costs for development wells, related plant and equipment, proved mineral interests in crude oil and natural gas properties, and related asset retirement obligation (ARO) assets are capitalized. Costs of exploratory wells are capitalized pending determination of whether the wells found proved reserves. Costs of wells that are assigned proved reserves remain capitalized. Costs also are capitalized for exploratory wells that have found crude oil and natural gas reserves even if the reserves cannot be classified as proved when the drilling is completed, provided the exploratory well has found a sufficient quantity of reserves to justify its completion as a producing well and the company is making sufficient progress assessing the reserves and the economic and operating viability of the project. All other exploratory wells and costs are expensed. Refer to Note 21, beginning on page FS-49, for additional discussion of accounting for suspended exploratory well costs. Long-lived assets to be held and used, including proved crude oil and natural gas properties, are assessed for possible impairment by comparing their carrying values with their associated undiscounted, future net before-tax cash flows. Events that can trigger assessments for possible impairments include write-downs of proved reserves based on field performance, significant decreases in the market value of an asset (including changes to the commodity price forecast), significant change in the extent or manner of use of or a physical change in an asset, and a more-likely-than-not expectation that a long-lived asset or asset group will be sold or otherwise disposed of significantly sooner than the end of its previously estimated useful life. Impaired assets are written down to their estimated fair values, generally their discounted, future net before-tax cash flows. For proved crude oil and natural gas properties, the company performs impairment reviews on a country, concession, PSC, development area or field basis, as appropriate. In Downstream, impairment reviews are performed on the basis of a refinery, a plant, a marketing/lubricants area or distribution area, as appropriate. Impairment amounts are recorded as incremental “Depreciation, depletion and amortization” expense. Long-lived assets that are held for sale are evaluated for possible impairment by comparing the carrying value of the asset with its fair value less the cost to sell. If the net book value exceeds the fair value less cost to sell, the asset is considered impaired and adjusted to the lower value. Refer to Note 9, beginning on page FS-34, relating to fair value measurements. The fair value of a liability for an ARO is recorded as an asset and a liability when there is a legal obligation associated with the retirement of a long-lived asset and the amount can be reasonably estimated. Refer also to Note 25, on page FS-59, relating to AROs. Depreciation and depletion of all capitalized costs of proved crude oil and natural gas producing properties, except mineral interests, are expensed using the unit-of-production method, generally by individual field, as the proved developed reserves are produced. Depletion expenses for capitalized costs of proved mineral interests are recognized using the unit-of-production method by individual field as the related proved reserves are produced. Periodic valuation provisions for impairment of capitalized costs of unproved mineral interests are expensed. The capitalized costs of all other plant and equipment are depreciated or amortized over their estimated useful lives. In general, the declining-balance method is used to depreciate plant and equipment in the United States; the straight-line method is generally used to depreciate international plant and equipment and to amortize all capitalized leased assets. Gains or losses are not recognized for normal retirements of properties, plant and equipment subject to composite group amortization or depreciation. Gains or losses from abnormal retirements are recorded as expenses, and from sales as “Other income.” Expenditures for maintenance (including those for planned major maintenance projects), repairs and minor renewals to maintain facilities in operating condition are generally expensed as incurred. Major replacements and renewals are capitalized. Goodwill Goodwill resulting from a business combination is not subject to amortization. The company tests such goodwill at the reporting unit level for impairment on an annual basis and between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of the reporting unit below its carrying amount. Environmental Expenditures Environmental expenditures that relate to ongoing operations or to conditions caused by past operations are expensed. Expenditures that create future benefits or contribute to future revenue generation are capitalized. Liabilities related to future remediation costs are recorded when environmental assessments or cleanups or both are probable and the costs can be reasonably estimated. For crude oil, natural gas and mineral-producing properties, a liability for an ARO is made in accordance with accounting standards for asset retirement and environmental obligations. Refer to Note 25, on page FS-59, for a discussion of the company’s AROs. For federal Superfund sites and analogous sites under state laws, the company records a liability for its designated share of the probable and estimable costs, and probable amounts for other potentially responsible parties when mandated by the regulatory agencies because the other parties are not able to pay their respective shares. The gross amount of environmental liabilities is based on the company’s best estimate of future costs using currently available technology and applying current regulations and the company’s own internal environmental policies. Future amounts are not discounted. Recoveries or reimbursements are recorded as assets when receipt is reasonably assured. Currency Translation The U.S. dollar is the functional currency for substantially all of the company’s consolidated operations and those of its equity affiliates. For those operations, all gains and losses from currency remeasurement are included in current period income. The cumulative translation effects for those few entities, both consolidated and affiliated, using functional currencies other than the U.S. dollar are included in “Currency translation adjustment” on the Consolidated Statement of Equity. Revenue Recognition Revenues associated with sales of crude oil, natural gas, petroleum and chemicals products, and all other sources are recorded when title passes to the customer, net of royalties, discounts and allowances, as applicable. Revenues from natural gas production from properties in which Chevron has an interest with other producers are generally recognized using the entitlement method. Excise, value-added and similar taxes assessed by a governmental authority on a revenue-producing transaction between a seller and a customer are presented on a gross basis. The associated amounts are shown as a footnote to the Consolidated Statement of Income, on page FS-23. Purchases and sales of inventory with the same counterparty that are entered into in contemplation of one another (including buy/sell arrangements) are combined and recorded on a net basis and reported in “Purchased crude oil and products” on the Consolidated Statement of Income. Stock Options and Other Share-Based Compensation The company issues stock options and other share-based compensation to certain employees. For equity awards, such as stock options, total compensation cost is based on the grant date fair value, and for liability awards, such as stock appreciation rights, total compensation cost is based on the settlement value. The company recognizes stock-based compensation expense for all awards over the service period required to earn the award, which is the shorter of the vesting period or the time period an employee becomes eligible to retain the award at retirement. Stock options and stock appreciation rights granted under the company’s Long-Term Incentive Plan have graded vesting provisions by which one-third of each award vests on the first, second and third anniversaries of the date of grant. The company amortizes these graded awards on a straight-line basis.

Changes in Accumulated Other Co

Changes in Accumulated Other Comprehensive Losses	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Changes in Accumulated Other Comprehensive Losses	Changes in Accumulated Other Comprehensive Losses The change in Accumulated Other Comprehensive Losses (AOCL) presented on the Consolidated Balance Sheet and the impact of significant amounts reclassified from AOCL on information presented in the Consolidated Statement of Income for the year ending December 31, 2015 , are reflected in the table below. Year Ended December 31, 2015 1 Currency Translation Adjustment Unrealized Holding Gains (Losses) on Securities Derivatives Defined Benefit Plans Total Balance at January 1 $ (96 ) $ (8 ) $ (2 ) $ (4,753 ) $ (4,859 ) Components of Other Comprehensive Income (Loss): Before Reclassifications (44 ) (21 ) — 126 61 Reclassifications 2 — — — 507 507 Net Other Comprehensive Income (Loss) (44 ) (21 ) — 633 568 Balance at December 31 $ (140 ) $ (29 ) $ (2 ) $ (4,120 ) $ (4,291 ) 1 All amounts are net of tax. 2 Refer to Note 23 beginning on page FS-51, for reclassified components totaling $824 that are included in employee benefit costs for the year ending December 31, 2015 . Related income taxes for the same period, totaling $317 , are reflected in Income Tax Expense on the Consolidated Statement of Income. All other reclassified amounts were insignificant.

Noncontrolling Interests

Noncontrolling Interests	12 Months Ended
	Dec. 31, 2015
Noncontrolling Interest [Abstract]
Noncontrolling Interests	Noncontrolling Interests Ownership interests in the company’s subsidiaries held by parties other than the parent are presented separately from the parent’s equity on the Consolidated Balance Sheet. The amount of consolidated net income attributable to the parent and the noncontrolling interests are both presented on the face of the Consolidated Statement of Income. The term “earnings” is defined as “Net Income Attributable to Chevron Corporation.” Activity for the equity attributable to noncontrolling interests for 2015 , 2014 and 2013 is as follows: 2015 2014 2013 Balance at January 1 $ 1,163 $ 1,314 $ 1,308 Net income 123 69 174 Distributions to noncontrolling interests (128 ) (47 ) (99 ) Other changes, net 12 (173 ) (69 ) Balance at December 31 $ 1,170 $ 1,163 $ 1,314

Information Relating to the Con

Information Relating to the Consolidated Statement of Cash Flows	12 Months Ended
	Dec. 31, 2015
Supplemental Cash Flow Elements [Abstract]
Information Relating to the Consolidated Statement of Cash Flows	Information Relating to the Consolidated Statement of Cash Flows Year ended December 31 2015 2014 2013 Net increase in operating working capital was composed of the following: Decrease (increase) in accounts and notes receivable $ 3,631 $ 4,491 $ (1,101 ) Decrease (increase) in inventories 85 (146 ) (237 ) Decrease (increase) in prepaid expenses and other current assets 713 (407 ) 834 (Decrease) increase in accounts payable and accrued liabilities (5,769 ) (3,737 ) 160 Decrease in income and other taxes payable (639 ) (741 ) (987 ) Net increase in operating working capital $ (1,979 ) $ (540 ) $ (1,331 ) Net cash provided by operating activities includes the following cash payments for income taxes: Income taxes $ 4,645 $ 10,562 $ 12,898 Net sales (purchases) of marketable securities consisted of the following gross amounts: Marketable securities purchased $ (6 ) $ (162 ) $ (7 ) Marketable securities sold 128 14 10 Net sales (purchases) of marketable securities $ 122 $ (148 ) $ 3 Net maturities of time deposits consisted of the following gross amounts: Investments in time deposits $ — $ (317 ) $ (2,317 ) Maturities of time deposits 8 317 3,017 Net maturities of time deposits $ 8 $ — $ 700 Net (repayments) borrowings of short-term obligations consisted of the following gross and net amounts: Proceeds from issuances of short-term obligations $ 13,805 $ 9,070 $ 1,551 Repayments of short-term obligations (16,379 ) (4,612 ) (375 ) Net borrowings (repayments) of short-term obligations with three months or less maturity 2,239 (1,027 ) 1,202 Net (repayments) borrowings of short-term obligations $ (335 ) $ 3,431 $ 2,378 The “ Net increase in operating working capital ” includes reductions of $17 , $58 and $79 for excess income tax benefits associated with stock options exercised during 2015 , 2014 and 2013 , respectively. These amounts are offset by an equal amount in “ Net sales (purchases) of treasury shares .” "Other" includes changes in postretirement benefits obligations and other long-term liabilities. The “ Net sales (purchases) of treasury shares ” represents the cost of common shares acquired less the cost of shares issued for share-based compensation plans. Purchases totaled $2 , $5,006 and $5,004 in 2015 , 2014 and 2013 , respectively. No purchases were made under the company's share repurchase program in 2015 . In 2014 and 2013 , the company purchased 41.5 million and 41.6 million common shares for $5,000 and $5,000 under its share repurchase program, respectively. In 2015 , 2014 and 2013 , “ Net sales (purchases) of other short-term investments ” generally consisted of restricted cash associated with upstream abandonment activities, tax payments, and funds held in escrow for tax-deferred exchanges and asset acquisitions and divestitures that was invested in cash and short-term securities and reclassified from “Cash and cash equivalents” to “Deferred charges and other assets” on the Consolidated Balance Sheet. The Consolidated Statement of Cash Flows excludes changes to the Consolidated Balance Sheet that did not affect cash. "Depreciation, depletion and amortization," "Dry hole expense" and "Deferred income tax provision" collectively include approximately $3,700 in non-cash reductions to properties, plant and equipment recorded in 2015 relating to impairments and project suspensions and associated adverse tax effects, primarily as a result of downward revisions in the company's longer-term crude oil price outlook. Refer also to Note 25, on page FS-59, for a discussion of revisions to the company’s AROs that also did not involve cash receipts or payments for the three years ending December 31, 2015 . The major components of “Capital expenditures” and the reconciliation of this amount to the reported capital and exploratory expenditures, including equity affiliates, are presented in the following table: Year ended December 31 2015 2014 2013 Additions to properties, plant and equipment * $ 28,213 $ 34,393 $ 36,550 Additions to investments 555 526 934 Current-year dry hole expenditures 736 504 594 Payments for other liabilities and assets, net — (16 ) (93 ) Capital expenditures 29,504 35,407 37,985 Expensed exploration expenditures 1,031 1,110 1,178 Assets acquired through capital lease obligations and other financing obligations 47 332 16 Capital and exploratory expenditures, excluding equity affiliates 30,582 36,849 39,179 Company's share of expenditures by equity affiliates 3,397 3,467 2,698 Capital and exploratory expenditures, including equity affiliates $ 33,979 $ 40,316 $ 41,877 * Excludes noncash additions of $1,362 in 2015 , $2,310 in 2014 and $1,661 in 2013 .

New Accounting Standards

New Accounting Standards	12 Months Ended
	Dec. 31, 2015
Accounting Standards [Abstract]
New Accounting Standards	New Accounting Standards Revenue Recognition (Topic 606), Revenue from Contracts with Customers (ASU 2014-09) In July 2015, the FASB approved a one-year deferral of the effective date of ASU 2014-09, which becomes effective for the company January 1, 2018. Early adoption is permitted at the original effective date of January 1, 2017. The standard provides a single comprehensive revenue recognition model for contracts with customers, eliminates most industry-specific revenue recognition guidance, and expands disclosure requirements. The company is evaluating the effect of the standard on its consolidated financial statements. The company does not intend to proceed with early adoption. Income Taxes (Topic 740), Balance Sheet Classification of Deferred Taxes (ASU 2015-17) In November 2015, FASB issued ASU 2015-17, which becomes effective for the company January 1, 2017. Early adoption is permitted. The standard provides that all deferred income taxes be classified as noncurrent on the balance sheet. The current requirement is to classify most deferred tax assets and liabilities based on the classification of the underlying asset or liability. Adoption of the standard will not have an impact on the company's results of operations or liquidity.

Lease Commitments

Lease Commitments	12 Months Ended
	Dec. 31, 2015
Leases [Abstract]
Lease Commitments	Lease Commitments Certain noncancelable leases are classified as capital leases, and the leased assets are included as part of “Properties, plant and equipment, at cost” on the Consolidated Balance Sheet. Such leasing arrangements involve crude oil production and processing equipment, service stations, bareboat charters, office buildings, and other facilities. Other leases are classified as operating leases and are not capitalized. The payments on operating leases are recorded as expense. Details of the capitalized leased assets are as follows: At December 31 2015 2014 Upstream $ 800 $ 765 Downstream 98 97 All Other — — Total 898 862 Less: Accumulated amortization 448 381 Net capitalized leased assets $ 450 $ 481 Rental expenses incurred for operating leases during 2015 , 2014 and 2013 were as follows: Year ended December 31 2015 2014 2013 Minimum rentals $ 1,041 $ 1,080 $ 1,049 Contingent rentals 2 1 1 Total 1,043 1,081 1,050 Less: Sublease rental income 9 14 25 Net rental expense $ 1,034 $ 1,067 $ 1,025 Contingent rentals are based on factors other than the passage of time, principally sales volumes at leased service stations. Certain leases include escalation clauses for adjusting rentals to reflect changes in price indices, renewal options ranging up to 25 years, and options to purchase the leased property during or at the end of the initial or renewal lease period for the fair market value or other specified amount at that time. At December 31, 2015 , the estimated future minimum lease payments (net of noncancelable sublease rentals) under operating and capital leases, which at inception had a noncancelable term of more than one year, were as follows: At December 31 Operating Leases Capital Leases Year 2016 $ 846 $ 23 2017 689 21 2018 554 19 2019 420 19 2020 311 6 Thereafter 528 62 Total $ 3,348 $ 150 Less: Amounts representing interest and executory costs $ (53 ) Net present values 97 Less: Capital lease obligations included in short-term debt (17 ) Long-term capital lease obligations $ 80

Summarized Financial Data - Che

Summarized Financial Data - Chevron U.S.A. Inc.	12 Months Ended
	Dec. 31, 2015
Chevron U.S.A. Inc. [Member]
Subsidiary Statements Captions [Line Items]
Summarized Financial Data - Chevron U.S.A. Inc.	Summarized Financial Data – Chevron U.S.A. Inc. Chevron U.S.A. Inc. (CUSA) is a major subsidiary of Chevron Corporation. CUSA and its subsidiaries manage and operate most of Chevron’s U.S. businesses. Assets include those related to the exploration and production of crude oil, natural gas and natural gas liquids and those associated with the refining, marketing, supply and distribution of products derived from petroleum, excluding most of the regulated pipeline operations of Chevron. CUSA also holds the company’s investment in the Chevron Phillips Chemical Company LLC joint venture, which is accounted for using the equity method. The summarized financial information for CUSA and its consolidated subsidiaries is as follows: Year ended December 31 2015 2014 2013 Sales and other operating revenues $ 97,766 $ 157,198 $ 174,318 Total costs and other deductions 101,565 153,139 169,984 Net income (loss) attributable to CUSA (1,054 ) 3,849 3,714 2015 2014 Current assets $ 9,732 $ 13,724 Other assets 59,170 62,195 Current liabilities 13,664 16,191 Other liabilities 29,100 30,175 Total CUSA net equity $ 26,138 $ 29,553 Memo: Total debt $ 14,462 $ 14,473

Summarized Financial Data - Ten

Summarized Financial Data - Tengizchevroil LLP	12 Months Ended
	Dec. 31, 2015
Summarized Financial Data of Affiliate [Abstract]
Summarized Financial Data - Tengizchevroil LLP	Summarized Financial Data – Tengizchevroil LLP Chevron has a 50 percent equity ownership interest in Tengizchevroil LLP (TCO). Refer to Note 15, beginning on page FS-40, for a discussion of TCO operations. Summarized financial information for 100 percent of TCO is presented in the table below: Year ended December 31 2015 2014 2013 Sales and other operating revenues $ 12,811 $ 22,813 $ 25,239 Costs and other deductions 7,257 10,275 11,173 Net income attributable to TCO 3,897 8,772 9,855 At December 31 2015 2014 Current assets $ 2,098 $ 3,425 Other assets 17,094 14,810 Current liabilities 1,063 1,531 Other liabilities 2,266 2,375 Total TCO net equity $ 15,863 $ 14,329

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The tables below and on the next page show the fair value hierarchy for assets and liabilities measured at fair value on a recurring and nonrecurring basis at December 31, 2015 , and December 31, 2014 . Marketable Securities The company calculates fair value for its marketable securities based on quoted market prices for identical assets. The fair values reflect the cash that would have been received if the instruments were sold at December 31, 2015 . Derivatives The company records its derivative instruments – other than any commodity derivative contracts that are designated as normal purchase and normal sale – on the Consolidated Balance Sheet at fair value, with the offsetting amount to the Consolidated Statement of Income. Derivatives classified as Level 1 include futures, swaps and options contracts traded in active markets such as the New York Mercantile Exchange. Derivatives classified as Level 2 include swaps, options and forward contracts principally with financial institutions and other oil and gas companies, the fair values of which are obtained from third-party broker quotes, industry pricing services and exchanges. The company obtains multiple sources of pricing information for the Level 2 instruments. Since this pricing information is generated from observable market data, it has historically been very consistent. The company does not materially adjust this information. Properties, Plant and Equipment The company reported impairments for certain oil and gas properties during 2015 primarily as a result of downward revisions in the company's longer-term crude oil price outlook. The impairments were primarily in Brazil and the United States. The company reported impairments for certain oil and gas properties and a mining asset in 2014 . Investments and Advances The company did not have any material investments and advances measured at fair value on a nonrecurring basis to report in 2015 or 2014 . Assets and Liabilities Measured at Fair Value on a Recurring Basis At Dec ember 31, 2015 At December 31, 2014 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Marketable securities $ 310 $ 310 $ — $ — $ 422 $ 422 $ — $ — Derivatives 205 189 16 — 413 394 19 — Total Assets at Fair Value $ 515 $ 499 $ 16 $ — $ 835 $ 816 $ 19 $ — Derivatives 53 47 6 — 84 83 1 — Total Liabilities at Fair Value $ 53 $ 47 $ 6 $ — $ 84 $ 83 $ 1 $ — Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis At December 31 At December 31 Before-Tax Loss Before-Tax Loss Total Level 1 Level 2 Level 3 Year 2015 Total Level 1 Level 2 Level 3 Year 2014 Properties, plant and equipment, net (held and used) $ 3,051 $ — $ 239 $ 2,812 $ 3,222 $ 947 $ — $ 213 $ 734 $ 1,249 Properties, plant and equipment, net (held for sale) 937 — 937 — 844 — — — — 25 Investments and advances 75 — 75 — 28 11 — — 11 41 Total Nonrecurring Assets at Fair Value $ 4,063 $ — $ 1,251 $ 2,812 $ 4,094 $ 958 $ — $ 213 $ 745 $ 1,315 Assets and Liabilities Not Required to Be Measured at Fair Value The company holds cash equivalents and time deposits in U.S. and non-U.S. portfolios. The instruments classified as cash equivalents are primarily bank time deposits with maturities of 90 days or less and money market funds. “Cash and cash equivalents” had carrying/fair values of $11,022 and $12,785 at December 31, 2015 , and December 31, 2014 , respectively. The instruments held in “Time deposits” are bank time deposits with maturities greater than 90 days, and had carrying/fair values of zero and $8 at December 31, 2015 , and December 31, 2014 , respectively. The fair values of cash, cash equivalents and bank time deposits are classified as Level 1 and reflect the cash that would have been received if the instruments were settled at December 31, 2015 . "Cash and cash equivalents” do not include investments with a carrying/fair value of $1,100 and $1,474 at December 31, 2015 , and December 31, 2014 , respectively. At December 31, 2015 , these investments are classified as Level 1 and include restricted funds related to upstream abandonment activities, tax payments, and funds held in escrow for tax-deferred exchanges and asset acquisitions and divestitures, which are reported in “Deferred charges and other assets” on the Consolidated Balance Sheet. Long-term debt of $25,584 and $15,960 at December 31, 2015 , and December 31, 2014 , had estimated fair values of $25,884 and $16,450 , respectively. Long-term debt primarily includes corporate issued bonds. The fair value of corporate bonds is $25,117 and classified as Level 1. The fair value of the other bonds is $767 and classified as Level 2. The carrying values of short-term financial assets and liabilities on the Consolidated Balance Sheet approximate their fair values. Fair value remeasurements of other financial instruments at December 31, 2015 and 2014 , were not material.

Financial and Derivative Instru

Financial and Derivative Instruments	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Financial and Derivative Instruments	Financial and Derivative Instruments Derivative Commodity Instruments The company’s derivative commodity instruments principally include crude oil, natural gas and refined product futures, swaps, options, and forward contracts. None of the company’s derivative instruments is designated as a hedging instrument, although certain of the company’s affiliates make such designation. The company’s derivatives are not material to the company’s financial position, results of operations or liquidity. The company believes it has no material market or credit risks to its operations, financial position or liquidity as a result of its commodity derivative activities. The company uses derivative commodity instruments traded on the New York Mercantile Exchange and on electronic platforms of the Inter-Continental Exchange and Chicago Mercantile Exchange. In addition, the company enters into swap contracts and option contracts principally with major financial institutions and other oil and gas companies in the “over-the-counter” markets, which are governed by International Swaps and Derivatives Association agreements and other master netting arrangements. Depending on the nature of the derivative transactions, bilateral collateral arrangements may also be required. Derivative instruments measured at fair value at December 31, 2015 , December 31, 2014 , and December 31, 2013 , and their classification on the Consolidated Balance Sheet and Consolidated Statement of Income are on the next page: Consolidated Balance Sheet: Fair Value of Derivatives Not Designated as Hedging Instruments At December 31 Type of Contract Balance Sheet Classification 2015 2014 Commodity Accounts and notes receivable, net $ 200 $ 401 Commodity Long-term receivables, net 5 12 Total Assets at Fair Value $ 205 $ 413 Commodity Accounts payable $ 51 $ 57 Commodity Deferred credits and other noncurrent obligations 2 27 Total Liabilities at Fair Value $ 53 $ 84 Consolidated Statement of Income: The Effect of Derivatives Not Designated as Hedging Instruments Gain/(Loss) Type of Derivative Statement of Year ended December 31 Contract Income Classification 2015 2014 2013 Commodity Sales and other operating revenues $ 277 $ 553 $ (108 ) Commodity Purchased crude oil and products 30 (17 ) (77 ) Commodity Other income (3 ) (32 ) (9 ) $ 304 $ 504 $ (194 ) The table below represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at December 31, 2015 and December 31, 2014 . Consolidated Balance Sheet: The Effect of Netting Derivative Assets and Liabilities Gross Amount Recognized Gross Amounts Offset Net Amounts Presented Gross Amounts Not Offset Net Amount At December 31, 2015 Derivative Assets $ 2,459 $ 2,254 $ 205 $ — $ 205 Derivative Liabilities $ 2,307 $ 2,254 $ 53 $ — $ 53 At December 31, 2014 Derivative Assets $ 4,004 $ 3,591 $ 413 $ 7 $ 406 Derivative Liabilities $ 3,675 $ 3,591 $ 84 $ — $ 84 Derivative assets and liabilities are classified on the Consolidated Balance Sheet as accounts and notes receivable, long-term receivables, accounts payable, and deferred credits and other noncurrent obligations. Amounts not offset on the Consolidated Balance Sheet represent positions that do not meet all the conditions for "a right of offset." Concentrations of Credit Risk The company’s financial instruments that are exposed to concentrations of credit risk consist primarily of its cash equivalents, time deposits, marketable securities, derivative financial instruments and trade receivables. The company’s short-term investments are placed with a wide array of financial institutions with high credit ratings. Company investment policies limit the company’s exposure both to credit risk and to concentrations of credit risk. Similar policies on diversification and creditworthiness are applied to the company’s counterparties in derivative instruments. The trade receivable balances, reflecting the company’s diversified sources of revenue, are dispersed among the company’s broad customer base worldwide. As a result, the company believes concentrations of credit risk are limited. The company routinely assesses the financial strength of its customers. When the financial strength of a customer is not considered sufficient, alternative risk mitigation measures may be deployed, including requiring pre-payments, letters of credit or other acceptable collateral instruments to support sales to customers.

Assets Held For Sale

Assets Held For Sale	12 Months Ended
	Dec. 31, 2015
Assets Held For Sale [Abstract]
Assets Held For Sale	Assets Held for Sale At December 31, 2015 , the company classified $1,449 of net properties, plant and equipment as “Assets held for sale” on the Consolidated Balance Sheet. These assets are associated with upstream and downstream operations that are anticipated to be sold in the next 12 months. The revenues and earnings contributions of these assets in 2015 were not material.

Equity

Equity	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Equity	Equity Retained earnings at December 31, 2015 and 2014 , included approximately $15,010 and $14,512 , respectively, for the company’s share of undistributed earnings of equity affiliates. At December 31, 2015 , about 114 million shares of Chevron’s common stock remained available for issuance from the 260 million shares that were reserved for issuance under the Chevron Long-Term Incentive Plan. In addition, approximately 120,753 shares remain available for issuance from the 800,000 shares of the company’s common stock that were reserved for awards under the Chevron Corporation Non-Employee Directors’ Equity Compensation and Deferral Plan.

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Share	Earnings Per Share Basic earnings per share (EPS) is based upon “Net Income Attributable to Chevron Corporation” (“earnings”) and includes the effects of deferrals of salary and other compensation awards that are invested in Chevron stock units by certain officers and employees of the company. Diluted EPS includes the effects of these items as well as the dilutive effects of outstanding stock options awarded under the company’s stock option programs (refer to Note 22, “Stock Options and Other Share-Based Compensation,” beginning on page FS-50). The table below sets forth the computation of basic and diluted EPS: Year ended December 31 2015 2014 2013 Basic EPS Calculation Earnings available to common stockholders - Basic * $ 4,587 $ 19,241 $ 21,423 Weighted-average number of common shares outstanding 1,867 1,883 1,916 Add: Deferred awards held as stock units 1 1 1 Total weighted-average number of common shares outstanding 1,868 1,884 1,917 Earnings per share of common stock - Basic $ 2.46 $ 10.21 $ 11.18 Diluted EPS Calculation Earnings available to common stockholders - Diluted * $ 4,587 $ 19,241 $ 21,423 Weighted-average number of common shares outstanding 1,867 1,883 1,916 Add: Deferred awards held as stock units 1 1 1 Add: Dilutive effect of employee stock-based awards 7 14 15 Total weighted-average number of common shares outstanding 1,875 1,898 1,932 Earnings per share of common stock - Diluted $ 2.45 $ 10.14 $ 11.09 * There was no effect of dividend equivalents paid on stock units or dilutive impact of employee stock-based awards on earnings.

Operating Segments and Geograph

Operating Segments and Geographic Data	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Operating Segments and Geographic Data	Operating Segments and Geographic Data Although each subsidiary of Chevron is responsible for its own affairs, Chevron Corporation manages its investments in these subsidiaries and their affiliates. The investments are grouped into two business segments, Upstream and Downstream, representing the company’s “reportable segments” and “operating segments.” Upstream operations consist primarily of exploring for, developing and producing crude oil and natural gas; liquefaction, transportation and regasification associated with liquefied natural gas (LNG); transporting crude oil by major international oil export pipelines; processing, transporting, storage and marketing of natural gas; and a gas-to-liquids plant. Downstream operations consist primarily of refining of crude oil into petroleum products; marketing of crude oil and refined products; transporting of crude oil and refined products by pipeline, marine vessel, motor equipment and rail car; and manufacturing and marketing of commodity petrochemicals, plastics for industrial uses, and fuel and lubricant additives. All Other activities of the company include worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities, and technology companies. The company’s segments are managed by “segment managers” who report to the “chief operating decision maker” (CODM). The segments represent components of the company that engage in activities (a) from which revenues are earned and expenses are incurred; (b) whose operating results are regularly reviewed by the CODM, which makes decisions about resources to be allocated to the segments and assesses their performance; and (c) for which discrete financial information is available. The company’s primary country of operation is the United States of America, its country of domicile. Other components of the company’s operations are reported as "International” (outside the United States). Segment Earnings The company evaluates the performance of its operating segments on an after-tax basis, without considering the effects of debt financing interest expense or investment interest income, both of which are managed by the company on a worldwide basis. Corporate administrative costs and assets are not allocated to the operating segments. However, operating segments are billed for the direct use of corporate services. Nonbillable costs remain at the corporate level in “All Other.” Earnings by major operating area are presented in the following table: Year ended December 31 2015 2014 2013 Upstream United States $ (4,055 ) $ 3,327 $ 4,044 International 2,094 13,566 16,765 Total Upstream (1,961 ) 16,893 20,809 Downstream United States 3,182 2,637 787 International 4,419 1,699 1,450 Total Downstream 7,601 4,336 2,237 Total Segment Earnings 5,640 21,229 23,046 All Other Interest income 65 77 80 Other (1,118 ) (2,065 ) (1,703 ) Net Income Attributable to Chevron Corporation $ 4,587 $ 19,241 $ 21,423 Segment Assets Segment assets do not include intercompany investments or receivables. Assets at year-end 2015 and 2014 are as follows: At December 31 2015 2014 1 Upstream United States $ 46,407 $ 49,343 International 163,217 152,736 Goodwill 4,588 4,593 Total Upstream 214,212 206,672 Downstream United States 21,408 23,068 International 14,982 17,723 Total Downstream 36,390 40,791 Total Segment Assets 250,602 247,463 All Other United States 5,076 6,603 International 10,425 11,960 Total All Other 15,501 18,563 Total Assets – United States 72,891 79,014 Total Assets – International 188,624 182,419 Goodwill 4,588 4,593 Total Assets $ 266,103 $ 266,026 1 2014 conformed to 2015 presentation. Segment Sales and Other Operating Revenues Operating segment sales and other operating revenues, including internal transfers, for the years 2015 , 2014 and 2013 , are presented in the table on the next page. Products are transferred between operating segments at internal product values that approximate market prices. Revenues for the upstream segment are derived primarily from the production and sale of crude oil and natural gas, as well as the sale of third-party production of natural gas. Revenues for the downstream segment are derived from the refining and marketing of petroleum products such as gasoline, jet fuel, gas oils, lubricants, residual fuel oils and other products derived from crude oil. This segment also generates revenues from the manufacture and sale of fuel and lubricant additives and the transportation and trading of refined products and crude oil. "All Other" activities include revenues from insurance operations, real estate activities and technology companies. Year ended December 31 2015 2014 2013 Upstream United States $ 4,117 $ 7,455 $ 8,052 Intersegment 8,631 15,455 16,865 Total United States 12,748 22,910 24,917 International 15,587 23,808 17,607 Intersegment 11,492 23,107 33,034 Total International 27,079 46,915 50,641 Total Upstream * 39,827 69,825 75,558 Downstream United States 48,420 73,942 80,272 Excise and similar taxes 4,426 4,633 4,792 Intersegment 26 31 39 Total United States 52,872 78,606 85,103 International 54,296 86,848 105,373 Excise and similar taxes 2,933 3,553 3,699 Intersegment 1,528 8,839 859 Total International 58,757 99,240 109,931 Total Downstream * 111,629 177,846 195,034 All Other United States 141 252 358 Intersegment 1,372 1,475 1,524 Total United States 1,513 1,727 1,882 International 5 3 3 Intersegment 37 28 31 Total International 42 31 34 Total All Other 1,555 1,758 1,916 Segment Sales and Other Operating Revenues United States 67,133 103,243 111,902 International 85,878 146,186 160,606 Total Segment Sales and Other Operating Revenues 153,011 249,429 272,508 Elimination of intersegment sales (23,086 ) (48,935 ) (52,352 ) Total Sales and Other Operating Revenues $ 129,925 $ 200,494 $ 220,156 * Effective January 1, 2014, International Upstream prospectively includes selected amounts previously recognized in International Downstream, which are not material to the segments. Segment Income Taxes Segment income tax expense for the years 2015 , 2014 and 2013 is as follows: Year ended December 31 2015 2014 2013 Upstream United States $ (2,041 ) $ 2,043 $ 2,333 International 1,214 9,217 12,470 Total Upstream (827 ) 11,260 14,803 Downstream United States 1,320 1,302 364 International 1,313 467 389 Total Downstream 2,633 1,769 753 All Other (1,674 ) (1,137 ) (1,248 ) Total Income Tax Expense $ 132 $ 11,892 $ 14,308 Other Segment Information Additional information for the segmentation of major equity affiliates is contained in Note 15, on page FS-40. Information related to properties, plant and equipment by segment is contained in Note 16, on page FS-41.

Investments and Advances

Investments and Advances	12 Months Ended
	Dec. 31, 2015
Investments in and Advances to Affiliates, Schedule of Investments [Abstract]
Investments and Advances	Investments and Advances Equity in earnings, together with investments in and advances to companies accounted for using the equity method and other investments accounted for at or below cost, is shown in the following table. For certain equity affiliates, Chevron pays its share of some income taxes directly. For such affiliates, the equity in earnings does not include these taxes, which are reported on the Consolidated Statement of Income as “Income tax expense.” Investments and Advances Equity in Earnings At December 31* Year ended December 31 2015 2014 2015 2014 2013 Upstream Tengizchevroil $ 8,077 $ 7,319 $ 1,939 $ 4,392 $ 4,957 Petropiar 679 794 180 26 339 Caspian Pipeline Consortium 1,342 1,487 162 191 113 Petroboscan 1,163 917 219 186 300 Angola LNG Limited 3,284 3,277 (417 ) (311 ) (111 ) Other 2,158 2,316 135 229 214 Total Upstream 16,703 16,110 2,218 4,713 5,812 Downstream GS Caltex Corporation 3,620 2,867 824 420 132 Chevron Phillips Chemical Company LLC 5,196 5,116 1,367 1,606 1,371 Caltex Australia Ltd. — 1,161 92 183 224 Other 1,077 1,048 186 180 199 Total Downstream 9,893 10,192 2,469 2,389 1,926 All Other Other (18 ) 33 (3 ) (4 ) (211 ) Total equity method $ 26,578 $ 26,335 $ 4,684 $ 7,098 $ 7,527 Other at or below cost 532 577 Total investments and advances $ 27,110 $ 26,912 Total United States $ 6,863 $ 6,787 $ 1,342 $ 1,623 $ 1,294 Total International $ 20,247 $ 20,125 $ 3,342 $ 5,475 $ 6,233 * 2014 conformed to 2015 presentation. Descriptions of major affiliates, including significant differences between the company’s carrying value of its investments and its underlying equity in the net assets of the affiliates, are as follows: Tengizchevroil Chevron has a 50 percent equity ownership interest in Tengizchevroil (TCO), which operates the Tengiz and Korolev crude oil fields in Kazakhstan. At December 31, 2015 , the company’s carrying value of its investment in TCO was about $150 higher than the amount of underlying equity in TCO’s net assets. This difference results from Chevron acquiring a portion of its interest in TCO at a value greater than the underlying book value for that portion of TCO’s net assets. See Note 8, on page FS-34, for summarized financial information for 100 percent of TCO. Petropiar Chevron has a 30 percent interest in Petropiar, a joint stock company which operates the Hamaca heavy-oil production and upgrading project in Venezuela’s Orinoco Belt. At December 31, 2015 , the company’s carrying value of its investment in Petropiar was approximately $160 less than the amount of underlying equity in Petropiar’s net assets. The difference represents the excess of Chevron’s underlying equity in Petropiar’s net assets over the net book value of the assets contributed to the venture. Caspian Pipeline Consortium Chevron has a 15 percent interest in the Caspian Pipeline Consortium, a variable interest entity, which provides the critical export route for crude oil from both TCO and Karachaganak. The company has investments and advances totaling $1,342 , which includes long-term loans of $1,098 at year-end 2015 . The loans were provided to fund 30 percent of the initial pipeline construction. The company is not the primary beneficiary of the consortium because it does not direct activities of the consortium and only receives its proportionate share of the financial returns. Petroboscan Chevron has a 39.2 percent interest in Petroboscan, a joint stock company which operates the Boscan Field in Venezuela. At December 31, 2015 , the company’s carrying value of its investment in Petroboscan was approximately $140 higher than the amount of underlying equity in Petroboscan’s net assets. The difference reflects the excess of the net book value of the assets contributed by Chevron over its underlying equity in Petroboscan’s net assets. Angola LNG Limited Chevron has a 36.4 percent interest in Angola LNG Limited, which processes and liquefies natural gas produced in Angola for delivery to international markets. GS Caltex Corporation Chevron owns 50 percent of GS Caltex Corporation, a joint venture with GS Energy. The joint venture imports, refines and markets petroleum products, petrochemicals and lubricants, predominantly in South Korea. Chevron Phillips Chemical Company LLC Chevron owns 50 percent of Chevron Phillips Chemical Company LLC. The other half is owned by Phillips 66. Caltex Australia Ltd. Chevron sold its 50 percent equity ownership interest in Caltex Australia Ltd. (CAL) in second quarter 2015. Other Information “Sales and other operating revenues” on the Consolidated Statement of Income includes $4,850 , $10,404 and $14,635 with affiliated companies for 2015 , 2014 and 2013 , respectively. “Purchased crude oil and products” includes $4,240 , $6,735 and $7,063 with affiliated companies for 2015 , 2014 and 2013 , respectively. “Accounts and notes receivable” on the Consolidated Balance Sheet includes $399 and $924 due from affiliated companies at December 31, 2015 and 2014 , respectively. “Accounts payable” includes $286 and $345 due to affiliated companies at December 31, 2015 and 2014 , respectively. The following table provides summarized financial information on a 100 percent basis for all equity affiliates as well as Chevron’s total share, which includes Chevron's net loans to affiliates of $410 , $874 and $1,129 at December 31, 2015 , 2014 and 2013 , respectively. Affiliates Chevron Share Year ended December 31 2015 2014 2013 2015 2014 2013 Total revenues $ 71,389 $ 123,003 $ 131,875 $ 33,492 $ 58,937 $ 63,101 Income before income tax expense 13,129 20,609 24,075 6,279 9,968 11,108 Net income attributable to affiliates 10,649 14,758 15,594 4,691 7,237 7,845 At December 31 Current assets $ 27,162 $ 35,662 $ 39,713 $ 10,657 $ 13,465 $ 15,156 Noncurrent assets 71,650 70,817 68,593 26,607 26,053 25,059 Current liabilities 20,559 25,308 29,642 7,351 9,588 11,587 Noncurrent liabilities 18,560 17,983 19,442 3,909 4,211 4,559 Total affiliates' net equity $ 59,693 $ 63,188 $ 59,222 $ 26,004 $ 25,719 $ 24,069

Properties, Plant and Equipment

Properties, Plant and Equipment	12 Months Ended
	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Properties, Plant and Equipment	Properties, Plant and Equipment 1 At December 31 Year ended December 31 Gross Investment at Cost Net Investment Additions at Cost 2 Depreciation Expense 3 2015 2014 2013 2015 2014 2013 2015 2014 2013 2015 2014 2013 Upstream United States $ 93,848 $ 96,850 $ 89,555 $ 43,125 $ 45,864 $ 41,831 $ 6,586 $ 9,688 $ 8,188 $ 8,545 $ 5,127 $ 4,412 International 208,395 192,637 169,623 127,459 118,926 104,100 19,993 24,920 27,383 10,803 9,688 8,336 Total Upstream 302,243 289,487 259,178 170,584 164,790 145,931 26,579 34,608 35,571 19,348 14,815 12,748 Downstream United States 23,202 22,640 22,407 10,807 11,019 11,481 696 588 1,154 878 886 780 International 9,177 9,334 9,303 4,090 4,219 4,139 365 530 653 355 396 360 Total Downstream 32,379 31,974 31,710 14,897 15,238 15,620 1,061 1,118 1,807 1,233 1,282 1,140 All Other United States 5,500 5,673 5,402 2,859 3,077 3,194 357 581 721 439 680 286 International 155 155 143 56 68 84 5 25 23 17 16 12 Total All Other 5,655 5,828 5,545 2,915 3,145 3,278 362 606 744 456 696 298 Total United States 122,550 125,163 117,364 56,791 59,960 56,506 7,639 10,857 10,063 9,862 6,693 5,478 Total International 217,727 202,126 179,069 131,605 123,213 108,323 20,363 25,475 28,059 11,175 10,100 8,708 Total $ 340,277 $ 327,289 $ 296,433 $ 188,396 $ 183,173 $ 164,829 $ 28,002 $ 36,332 $ 38,122 $ 21,037 $ 16,793 $ 14,186 1 Other than the United States, Australia and Nigeria, no other country accounted for 10 percent or more of the company’s net properties, plant and equipment (PP&E) in 2015 . Australia had $49,205 , $41,012 and $31,464 in 2015 , 2014 , and 2013 , respectively. Nigeria had PP&E of $18,773 , $19,214 and $18,429 for 2015 , 2014 and 2013 , respectively. 2 Net of dry hole expense related to prior years’ expenditures of $1,573 , $371 and $89 in 2015 , 2014 and 2013 , respectively. 3 Depreciation expense includes accretion expense of $715 , $882 and $627 in 2015 , 2014 and 2013 , respectively, and impairments of $4,066 , $1,274 and $382 in 2015 , 2014 and 2013 , respectively.

Litigation

Litigation	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Litigation	Litigation MTBE Chevron and many other companies in the petroleum industry have used methyl tertiary butyl ether (MTBE) as a gasoline additive. Chevron is a party to seven pending lawsuits and claims, the majority of which involve numerous other petroleum marketers and refiners. Resolution of these lawsuits and claims may ultimately require the company to correct or ameliorate the alleged effects on the environment of prior release of MTBE by the company or other parties. Additional lawsuits and claims related to the use of MTBE, including personal-injury claims, may be filed in the future. The company’s ultimate exposure related to pending lawsuits and claims is not determinable. The company no longer uses MTBE in the manufacture of gasoline in the United States. Ecuador Background Chevron is a defendant in a civil lawsuit initiated in the Superior Court of Nueva Loja in Lago Agrio, Ecuador, in May 2003 by plaintiffs who claim to be representatives of certain residents of an area where an oil production consortium formerly had operations. The lawsuit alleges damage to the environment from the oil exploration and production operations and seeks unspecified damages to fund environmental remediation and restoration of the alleged environmental harm, plus a health monitoring program. Until 1992, Texaco Petroleum Company (Texpet), a subsidiary of Texaco Inc., was a minority member of this consortium with Petroecuador, the Ecuadorian state-owned oil company, as the majority partner; since 1990, the operations have been conducted solely by Petroecuador. At the conclusion of the consortium and following an independent third-party environmental audit of the concession area, Texpet entered into a formal agreement with the Republic of Ecuador and Petroecuador for Texpet to remediate specific sites assigned by the government in proportion to Texpet’s ownership share of the consortium. Pursuant to that agreement, Texpet conducted a three -year remediation program at a cost of $40 . After certifying that the sites were properly remediated, the government granted Texpet and all related corporate entities a full release from any and all environmental liability arising from the consortium operations. Based on the history described above, Chevron believes that this lawsuit lacks legal or factual merit. As to matters of law, the company believes first, that the court lacks jurisdiction over Chevron; second, that the law under which plaintiffs bring the action, enacted in 1999, cannot be applied retroactively; third, that the claims are barred by the statute of limitations in Ecuador; and, fourth, that the lawsuit is also barred by the releases from liability previously given to Texpet by the Republic of Ecuador and Petroecuador and by the pertinent provincial and municipal governments. With regard to the facts, the company believes that the evidence confirms that Texpet’s remediation was properly conducted and that the remaining environmental damage reflects Petroecuador’s failure to timely fulfill its legal obligations and Petroecuador’s further conduct since assuming full control over the operations. Lago Agrio Judgment In 2008, a mining engineer appointed by the court to identify and determine the cause of environmental damage, and to specify steps needed to remediate it, issued a report recommending that the court assess $18,900 , which would, according to the engineer, provide financial compensation for purported damages, including wrongful death claims, and pay for, among other items, environmental remediation, health care systems and additional infrastructure for Petroecuador. The engineer’s report also asserted that an additional $8,400 could be assessed against Chevron for unjust enrichment. In 2009, following the disclosure by Chevron of evidence that the judge participated in meetings in which businesspeople and individuals holding themselves out as government officials discussed the case and its likely outcome, the judge presiding over the case was recused. In 2010, Chevron moved to strike the mining engineer’s report and to dismiss the case based on evidence obtained through discovery in the United States indicating that the report was prepared by consultants for the plaintiffs before being presented as the mining engineer’s independent and impartial work and showing further evidence of misconduct. In August 2010, the judge issued an order stating that he was not bound by the mining engineer’s report and requiring the parties to provide their positions on damages within 45 days . Chevron subsequently petitioned for recusal of the judge, claiming that he had disregarded evidence of fraud and misconduct and that he had failed to rule on a number of motions within the statutory time requirement. In September 2010, Chevron submitted its position on damages, asserting that no amount should be assessed against it. The plaintiffs’ submission, which relied in part on the mining engineer’s report, took the position that damages are between approximately $16,000 and $76,000 and that unjust enrichment should be assessed in an amount between approximately $5,000 and $38,000 . The next day, the judge issued an order closing the evidentiary phase of the case and notifying the parties that he had requested the case file so that he could prepare a judgment. Chevron petitioned to have that order declared a nullity in light of Chevron’s prior recusal petition, and because procedural and evidentiary matters remained unresolved. In October 2010, Chevron’s motion to recuse the judge was granted. A new judge took charge of the case and revoked the prior judge’s order closing the evidentiary phase of the case. On December 17, 2010, the judge issued an order closing the evidentiary phase of the case and notifying the parties that he had requested the case file so that he could prepare a judgment. On February 14, 2011, the provincial court in Lago Agrio rendered an adverse judgment in the case. The court rejected Chevron’s defenses to the extent the court addressed them in its opinion. The judgment assessed approximately $8,600 in damages and approximately $900 as an award for the plaintiffs’ representatives. It also assessed an additional amount of approximately $8,600 in punitive damages unless the company issued a public apology within 15 days of the judgment, which Chevron did not do. On February 17, 2011, the plaintiffs appealed the judgment, seeking increased damages, and on March 11, 2011, Chevron appealed the judgment seeking to have the judgment nullified. On January 3, 2012, an appellate panel in the provincial court affirmed the February 14, 2011 decision and ordered that Chevron pay additional attorneys’ fees in the amount of “ 0.10% of the values that are derived from the decisional act of this judgment.” The plaintiffs filed a petition to clarify and amplify the appellate decision on January 6, 2012, and the court issued a ruling in response on January 13, 2012, purporting to clarify and amplify its January 3, 2012 ruling, which included clarification that the deadline for the company to issue a public apology to avoid the additional amount of approximately $8,600 in punitive damages was within 15 days of the clarification ruling, or February 3, 2012. Chevron did not issue an apology because doing so might be mischaracterized as an admission of liability and would be contrary to facts and evidence submitted at trial. On January 20, 2012, Chevron appealed (called a petition for cassation) the appellate panel’s decision to Ecuador’s National Court of Justice. As part of the appeal, Chevron requested the suspension of any requirement that Chevron post a bond to prevent enforcement under Ecuadorian law of the judgment during the cassation appeal. On February 17, 2012, the appellate panel of the provincial court admitted Chevron’s cassation appeal in a procedural step necessary for the National Court of Justice to hear the appeal. The provincial court appellate panel denied Chevron’s request for suspension of the requirement that Chevron post a bond and stated that it would not comply with the First and Second Interim Awards of the international arbitration tribunal discussed below. On March 29, 2012, the matter was transferred from the provincial court to the National Court of Justice, and on November 22, 2012, the National Court agreed to hear Chevron's cassation appeal. On August 3, 2012, the provincial court in Lago Agrio approved a court-appointed liquidator’s report on damages that calculated the total judgment in the case to be $19,100 . On November 13, 2013, the National Court ratified the judgment but nullified the $8,600 punitive damage assessment, resulting in a judgment of $9,500 . On December 23, 2013, Chevron appealed the decision to the Ecuador Constitutional Court, Ecuador's highest court. The reporting justice of the Constitutional Court heard oral arguments on the appeal on July 16, 2015. On July 2, 2013, the provincial court in Lago Agrio issued an embargo order in Ecuador ordering that any funds to be paid by the Government of Ecuador to Chevron to satisfy a $96 award issued in an unrelated action by an arbitral tribunal presiding in the Permanent Court of Arbitration in The Hague under the Rules of the United Nations Commission on International Trade Law must be paid to the Lago Agrio plaintiffs. The award was issued by the tribunal under the United States-Ecuador Bilateral Investment Treaty in an action filed in 2006 in connection with seven breach of contract cases that Texpet filed against the Government of Ecuador between 1991 and 1993. The Government of Ecuador has moved to set aside the tribunal's award. On September 26, 2014, the Supreme Court of the Netherlands issued an opinion denying Ecuador’s set aside request. A Federal District Court for the District of Columbia confirmed the tribunal's award, and on August 4, 2015, a panel of the U.S. Court of Appeals for the District of Columbia Circuit affirmed the District Court's decision. On September 9, 2015, the Court of Appeals denied the Government of Ecuador's request for full appellate court review of the Federal District Court's decision. Lago Agrio Plaintiffs' Enforcement Actions Chevron has no assets in Ecuador and the Lago Agrio plaintiffs' lawyers have stated in press releases and through other media that they will seek to enforce the Ecuadorian judgment in various countries and otherwise disrupt Chevron's operations. On May 30, 2012, the Lago Agrio plaintiffs filed an action against Chevron Corporation, Chevron Canada Limited, and Chevron Canada Finance Limited in the Ontario Superior Court of Justice in Ontario, Canada, seeking to recognize and enforce the Ecuadorian judgment. On May 1, 2013, the Ontario Superior Court of Justice held that the Court has jurisdiction over Chevron and Chevron Canada Limited for purposes of the action, but stayed the action due to the absence of evidence that Chevron Corporation has assets in Ontario. The Lago Agrio plaintiffs appealed that decision and on December 17, 2013, the Court of Appeals for Ontario affirmed the lower court’s decision on jurisdiction and set aside the stay, allowing the recognition and enforcement action to be heard in the Ontario Superior Court of Justice. Chevron appealed the decision to the Supreme Court of Canada and, on September 4, 2015, the Supreme Court dismissed the appeal and affirmed that the Ontario Superior Court of Justice has jurisdiction over Chevron and Chevron Canada Limited for purposes of the action. The recognition and enforcement proceeding and related preliminary motions are proceeding in the Ontario Superior Court of Justice. On June 27, 2012, the Lago Agrio plaintiffs filed a complaint against Chevron Corporation in the Superior Court of Justice in Brasilia, Brazil, seeking to recognize and enforce the Ecuadorian judgment. Chevron has answered the complaint. In accordance with Brazilian procedure, the matter was referred to the public prosecutor for a nonbinding opinion of the issues raised in the complaint. On May 13, 2015, the public prosecutor issued its nonbinding opinion and recommended that the Superior Court of Justice reject the plaintiffs' recognition and enforcement request, finding, among other things, that the Lago Agrio judgment was procured through fraud and corruption and cannot be recognized in Brazil because it violates Brazilian and international public order. On October 15, 2012, the provincial court in Lago Agrio issued an ex parte embargo order that purports to order the seizure of assets belonging to separate Chevron subsidiaries in Ecuador, Argentina and Colombia. On November 6, 2012, at the request of the Lago Agrio plaintiffs, a court in Argentina issued a Freeze Order against Chevron Argentina S.R.L. and another Chevron subsidiary, Ingeniero Norberto Priu, requiring shares of both companies to be "embargoed," requiring third parties to withhold 40 percent of any payments due to Chevron Argentina S.R.L. and ordering banks to withhold 40 percent of the funds in Chevron Argentina S.R.L. bank accounts. On December 14, 2012, the Argentinean court rejected a motion to revoke the Freeze Order but modified it by ordering that third parties are not required to withhold funds but must report their payments. The court also clarified that the Freeze Order relating to bank accounts excludes taxes. On January 30, 2013, an appellate court upheld the Freeze Order, but on June 4, 2013 the Supreme Court of Argentina revoked the Freeze Order in its entirety. On December 12, 2013, the Lago Agrio plaintiffs served Chevron with notice of their filing of an enforcement proceeding in the National Court, First Instance, of Argentina. Chevron filed its answer on February 27, 2014, to which the Lago Agrio plaintiffs responded on December 29, 2015. Chevron continues to believe the provincial court’s judgment is illegitimate and unenforceable in Ecuador, the United States and other countries. The company also believes the judgment is the product of fraud, and contrary to the legitimate scientific evidence. Chevron cannot predict the timing or ultimate outcome of the appeals process in Ecuador or any enforcement action. Chevron expects to continue a vigorous defense of any imposition of liability in the Ecuadorian courts and to contest and defend any and all enforcement actions. Company's Bilateral Investment Treaty Arbitration Claims Chevron and Texpet filed an arbitration claim in September 2009 against the Republic of Ecuador before an arbitral tribunal presiding in the Permanent Court of Arbitration in The Hague under the Rules of the United Nations Commission on International Trade Law. The claim alleges violations of the Republic of Ecuador’s obligations under the United States–Ecuador Bilateral Investment Treaty (BIT) and breaches of the settlement and release agreements between the Republic of Ecuador and Texpet (described above), which are investment agreements protected by the BIT. Through the arbitration, Chevron and Texpet are seeking relief against the Republic of Ecuador, including a declaration that any judgment against Chevron in the Lago Agrio litigation constitutes a violation of Ecuador’s obligations under the BIT. On February 9, 2011, the Tribunal issued an Order for Interim Measures requiring the Republic of Ecuador to take all measures at its disposal to suspend or cause to be suspended the enforcement or recognition within and without Ecuador of any judgment against Chevron in the Lago Agrio case pending further order of the Tribunal. On January 25, 2012, the Tribunal converted the Order for Interim Measures into an Interim Award. Chevron filed a renewed application for further interim measures on January 4, 2012, and the Republic of Ecuador opposed Chevron’s application and requested that the existing Order for Interim Measures be vacated on January 9, 2012. On February 16, 2012, the Tribunal issued a Second Interim Award mandating that the Republic of Ecuador take all measures necessary (whether by its judicial, legislative or executive branches) to suspend or cause to be suspended the enforcement and recognition within and without Ecuador of the judgment against Chevron and, in particular, to preclude any certification by the Republic of Ecuador that would cause the judgment to be enforceable against Chevron. On February 27, 2012, the Tribunal issued a Third Interim Award confirming its jurisdiction to hear Chevron's arbitration claims. On February 7, 2013, the Tribunal issued its Fourth Interim Award in which it declared that the Republic of Ecuador “has violated the First and Second Interim Awards under the [BIT], the UNCITRAL Rules and international law in regard to the finalization and enforcement subject to execution of the Lago Agrio Judgment within and outside Ecuador, including (but not limited to) Canada, Brazil and Argentina.” The Republic of Ecuador subsequently filed in the District Court of the Hague a request to set aside the Tribunal’s Interim Awards and the First Partial Award (described below), and on January 20, 2016, the District Court denied the Republic's request. The Tribunal has divided the merits phase of the proceeding into three phases. On September 17, 2013, the Tribunal issued its First Partial Award from Phase One, finding that the settlement agreements between the Republic of Ecuador and Texpet applied to Texpet and Chevron, released Texpet and Chevron from claims based on "collective" or "diffuse" rights arising from Texpet's operations in the former concession area and precluded third parties from asserting collective/diffuse rights environmental claims relating to Texpet's operations in the former concession area but did not preclude individual claims for personal harm. The Tribunal held a hearing on April 29-30, 2014, to address remaining issues relating to Phase One, and on March 12, 2015, it issued a nonbinding decision that the Lago Agrio plaintiffs' complaint, on its face, includes claims not barred by the settlement agreement between the Republic of Ecuador and Texpet. In the same decision, the Tribunal deferred to Phase Two remaining issues from Phase One, including whether the Republic of Ecuador breached the 1995 settlement agreement and the remedies that are available to Chevron and Texpet as a result of that breach. Phase Two issues were addressed at a hearing held in April and May 2015. The Tribunal has not set a date for Phase Three, the damages phase of the arbitration. Company's RICO Action Through a series of U.S. court proceedings initiated by Chevron to obtain discovery relating to the Lago Agrio litigation and the BIT arbitration, Chevron obtained evidence that it believes shows a pattern of fraud, collusion, corruption, and other misconduct on the part of several lawyers, consultants and others acting for the Lago Agrio plaintiffs. In February 2011, Chevron filed a civil lawsuit in the Federal District Court for the Southern District of New York against the Lago Agrio plaintiffs and several of their lawyers, consultants and supporters, alleging violations of the Racketeer Influenced and Corrupt Organizations Act and other state laws. Through the civil lawsuit, Chevron is seeking relief that includes a declaration that any judgment against Chevron in the Lago Agrio litigation is the result of fraud and other unlawful conduct and is therefore unenforceable. On March 7, 2011, the Federal District Court issued a preliminary injunction prohibiting the Lago Agrio plaintiffs and persons acting in concert with them from taking any action in furtherance of recognition or enforcement of any judgment against Chevron in the Lago Agrio case pending resolution of Chevron’s civil lawsuit by the Federal District Court. On May 31, 2011, the Federal District Court severed claims one through eight of Chevron’s complaint from the ninth claim for declaratory relief and imposed a discovery stay on claims one through eight pending a trial on the ninth claim for declaratory relief. On September 19, 2011, the U.S. Court of Appeals for the Second Circuit vacated the preliminary injunction, stayed the trial on Chevron’s ninth claim, a claim for declaratory relief, that had been set for November 14, 2011, and denied the defendants’ mandamus petition to recuse the judge hearing the lawsuit. The Second Circuit issued its opinion on January 26, 2012 ordering the dismissal of Chevron’s ninth claim for declaratory relief. On February 16, 2012, the Federal District Court lifted the stay on claims one through eight, and on October 18, 2012, the Federal District Court set a trial date of October 15, 2013. On March 22, 2013, Chevron settled its claims against Stratus Consulting, and on April 12, 2013 sworn declarations by representatives of Stratus Consulting were filed with the Court admitting their role and that of the plaintiffs' attorneys in drafting the environmental report of the mining engineer appointed by the provincial court in Lago Agrio. On September 26, 2013, the Second Circuit denied the defendants' Petition for Writ of Mandamus to recuse the judge hearing the case and to collaterally estop Chevron from seeking a declaration that the Lago Agrio judgment was obtained through fraud and other unlawful conduct. The trial commenced on October 15, 2013 and concluded on November 22, 2013. On March 4, 2014, the Federal District Court entered a judgment in favor of Chevron, prohibiting the defendants from seeking to enforce the Lago Agrio judgment in the United States and further prohibiting them from profiting from their illegal acts. The defendants appealed the Federal District Court's decision, and, on April 20, 2015, a panel of the U.S. Court of Appeals for the Second Circuit heard oral arguments. Management's Assessment The ultimate outcome of the foregoing matters, including any financial effect on Chevron, remains uncertain. Management does not believe an estimate of a reasonably possible loss (or a range of loss) can be made in this case. Due to the defects associated with the Ecuadorian judgment, the 2008 engineer’s report on alleged damages and the September 2010 plaintiffs’ submission on alleged damages, management does not believe these documents have any utility in calculating a reasonably possible loss (or a range of loss). Moreover, the highly uncertain legal environment surrounding the case provides no basis for management to estimate a reasonably possible loss (or a range of loss).

Taxes

Taxes	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Taxes	Taxes Income Taxes Year ended December 31 2015 2014 2013 Income tax expense (benefit) U.S. federal Current $ (817 ) $ 748 $ 15 Deferred (580 ) 1,330 1,128 State and local Current (187 ) 336 120 Deferred (109 ) 36 74 Total United States (1,693 ) 2,450 1,337 International Current 2,997 9,235 12,296 Deferred (1,172 ) 207 675 Total International 1,825 9,442 12,971 Total income tax expense (benefit) $ 132 $ 11,892 $ 14,308 In 2015 , before-tax loss for U.S. operations, including related corporate and other charges, was $(2,877) , compared with before-tax income of $6,296 and $4,672 in 2014 and 2013 , respectively. For international operations, before-tax income was $7,719 , $24,906 and $31,233 in 2015 , 2014 and 2013 , respectively. U.S. federal income tax expense was reduced by $35 , $68 and $175 in 2015 , 2014 and 2013 , respectively, for business tax credits. The reconciliation between the U.S. statutory federal income tax rate and the company’s effective income tax rate is detailed in the following table: Year ended December 31 2015 2014 2013 U.S. statutory federal income tax rate 35.0 % 35.0 % 35.0 % Effect of income taxes from international operations 1 (25.1 ) 2.1 4.4 State and local taxes on income, net of U.S. federal income tax benefit (1.5 ) 0.7 0.6 Tax credits (0.7 ) (0.2 ) (0.5 ) Other 1,2 (5.0 ) 0.5 0.4 Effective tax rate 2.7 % 38.1 % 39.9 % 1 2013 and 2014 conformed to 2015 presentation. 2 2015 includes one-time tax benefits associated with changes in uncertain tax positions and provision-to-return adjustments. The company’s effective tax rate decreased from 38.1 percent in 2014 to 2.7 percent in 2015 . The decrease primarily resulted from the impacts of jurisdictional mix, one-time tax benefits, foreign currency remeasurement, equity earnings and a reduction in statutory tax rates in the United Kingdom, partially offset by the effects of valuation allowances recognized on deferred tax assets and the sale of the company's interest in Caltex Australia Limited. The company records its deferred taxes on a tax-jurisdiction basis and classifies those net amounts as current or noncurrent based on the balance sheet classification of the related assets or liabilities. The reported deferred tax balances are composed of the following: At December 31 2015 2014 Deferred tax liabilities Properties, plant and equipment $ 27,044 $ 28,452 Investments and other 3,743 3,059 Total deferred tax liabilities 30,787 31,511 Deferred tax assets Foreign tax credits (10,534 ) (11,867 ) Abandonment/environmental reserves (6,880 ) (6,686 ) Employee benefits (4,801 ) (4,831 ) Deferred credits (1,810 ) (1,828 ) Tax loss carryforwards (2,748 ) (1,747 ) Other accrued liabilities (525 ) (498 ) Inventory (120 ) (153 ) Miscellaneous (2,525 ) (2,128 ) Total deferred tax assets (29,943 ) (29,738 ) Deferred tax assets valuation allowance 15,412 16,292 Total deferred taxes, net $ 16,256 $ 18,065 Deferred tax liabilities at the end of 2015 decreased by approximately $700 from year-end 2014 . The decrease was primarily related to decreased temporary differences related to property, plant and equipment. Deferred tax assets were essentially unchanged between periods. A reduction in U.S. foreign tax credits was substantially offset by an increase in foreign tax loss carryforwards. The overall valuation allowance relates to deferred tax assets for U.S. foreign tax credit carryforwards, tax loss carryforwards and temporary differences. It reduces the deferred tax assets to amounts that are, in management’s assessment, more likely than not to be realized. At the end of 2015 , the company had tax loss carryforwards of approximately $7,615 and tax credit carryforwards of approximately $1,249 , primarily related to various international tax jurisdictions. Whereas some of these tax loss carryforwards do not have an expiration date, others expire at various times from 2016 through 2025 . U.S. foreign tax credit carryforwards of $10,534 will expire between 2017 and 2024 . At December 31, 2015 and 2014 , deferred taxes were classified on the Consolidated Balance Sheet as follows: At December 31 2015 2014 Prepaid expenses and other current assets $ (917 ) $ (1,071 ) Deferred charges and other assets (4,512 ) (3,597 ) Federal and other taxes on income 996 813 Noncurrent deferred income taxes 20,689 21,920 Total deferred income taxes, net $ 16,256 $ 18,065 Income taxes are not accrued for unremitted earnings of international operations that have been or are intended to be reinvested indefinitely. Undistributed earnings of international consolidated subsidiaries and affiliates for which no deferred income tax provision has been made for possible future remittances totaled approximately $45,400 at December 31, 2015 . This amount represents earnings reinvested as part of the company’s ongoing international business. It is not practicable to estimate the amount of taxes that might be payable on the possible remittance of earnings that are intended to be reinvested indefinitely. At the end of 2015 , deferred income taxes were recorded for the undistributed earnings of certain international operations where indefinite reinvestment of the earnings is not planned. The company does not anticipate incurring significant additional taxes on remittances of earnings that are not indefinitely reinvested. Uncertain Income Tax Positions The company recognizes a tax benefit in the financial statements for an uncertain tax position only if management’s assessment is that the position is “more likely than not” (i.e., a likelihood greater than 50 percent ) to be allowed by the tax jurisdiction based solely on the technical merits of the position. The term “tax position” in the accounting standards for income taxes refers to a position in a previously filed tax return or a position expected to be taken in a future tax return that is reflected in measuring current or deferred income tax assets and liabilities for interim or annual periods. The following table indicates the changes to the company’s unrecognized tax benefits for the years ended December 31, 2015 , 2014 and 2013 . The term “unrecognized tax benefits” in the accounting standards for income taxes refers to the differences between a tax position taken or expected to be taken in a tax return and the benefit measured and recognized in the financial statements. Interest and penalties are not included. 2015 2014 2013 Balance at January 1 $ 3,552 $ 3,848 $ 3,071 Foreign currency effects (27 ) (25 ) (58 ) Additions based on tax positions taken in current year 154 354 276 Additions/reductions resulting from current-year asset acquisitions/sales — (22 ) — Additions for tax positions taken in prior years 218 37 1,164 Reductions for tax positions taken in prior years (678 ) (561 ) (176 ) Settlements with taxing authorities in current year (5 ) (50 ) (320 ) Reductions as a result of a lapse of the applicable statute of limitations (172 ) (29 ) (109 ) Balance at December 31 $ 3,042 $ 3,552 $ 3,848 The decrease in unrecognized tax benefits between December 31, 2014, and December 31, 2015 was primarily due to the resolution of numerous audit issues with various tax jurisdictions during the year. Approximately 71 percent of the $3,042 of unrecognized tax benefits at December 31, 2015 , would have an impact on the effective tax rate if subsequently recognized. Certain of these unrecognized tax benefits relate to tax carryforwards that may require a full valuation allowance at the time of any such recognition. Tax positions for Chevron and its subsidiaries and affiliates are subject to income tax audits by many tax jurisdictions throughout the world. For the company’s major tax jurisdictions, examinations of tax returns for certain prior tax years had not been completed as of December 31, 2015 . For these jurisdictions, the latest years for which income tax examinations had been finalized were as follows: United States – 2011 , Nigeria – 2000 , Angola – 2009 , Saudi Arabia – 2012 and Kazakhstan – 2007 . The company engages in ongoing discussions with tax authorities regarding the resolution of tax matters in the various jurisdictions. Both the outcome of these tax matters and the timing of resolution and/or closure of the tax audits are highly uncertain. However, it is reasonably possible that developments on tax matters in certain tax jurisdictions may result in significant increases or decreases in the company’s total unrecognized tax benefits within the next 12 months. Given the number of years that still remain subject to examination and the number of matters being examined in the various tax jurisdictions, the company is unable to estimate the range of possible adjustments to the balance of unrecognized tax benefits. On the Consolidated Statement of Income, the company reports interest and penalties related to liabilities for uncertain tax positions as “Income tax expense.” As of December 31, 2015 , accruals of $399 for anticipated interest and penalty obligations were included on the Consolidated Balance Sheet, compared with accruals of $233 as of year-end 2014 . Income tax expense (benefit) associated with interest and penalties was $195 , $4 and $(42) in 2015 , 2014 and 2013 , respectively. Taxes Other Than on Income Year ended December 31 2015 2014 2013 United States Excise and similar taxes on products and merchandise $ 4,426 $ 4,633 $ 4,792 Import duties and other levies 4 6 4 Property and other miscellaneous taxes 1,367 1,002 1,036 Payroll taxes 270 273 255 Taxes on production 157 349 333 Total United States 6,224 6,263 6,420 International Excise and similar taxes on products and merchandise 2,933 3,553 3,700 Import duties and other levies 40 45 41 Property and other miscellaneous taxes 2,548 2,277 2,486 Payroll taxes 161 172 168 Taxes on production 124 230 248 Total International 5,806 6,277 6,643 Total taxes other than on income $ 12,030 $ 12,540 $ 13,063

Short-Term Debt

Short-Term Debt	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Short-Term Debt	Short-Term Debt At December 31 2015 2014 Commercial paper * $ 8,252 $ 8,506 Notes payable to banks and others with originating terms of one year or less 20 104 Current maturities of long-term debt 1,487 — Current maturities of long-term capital leases 17 22 Redeemable long-term obligations Long-term debt 3,152 3,152 Capital leases — 6 Subtotal 12,928 11,790 Reclassified to long-term debt (8,000 ) (8,000 ) Total short-term debt $ 4,928 $ 3,790 * Weighted-average interest rates at December 31, 2015 and 2014 , were 0.26 percent and 0.12 percent , respectively. Redeemable long-term obligations consist primarily of tax-exempt variable-rate put bonds that are included as current liabilities because they become redeemable at the option of the bondholders during the year following the balance sheet date. The company may periodically enter into interest rate swaps on a portion of its short-term debt. At December 31, 2015 , the company had no interest rate swaps on short-term debt. At December 31, 2015 , the company had $8,000 in committed credit facilities with various major banks that enable the refinancing of short-term obligations on a long-term basis. The credit facilities consist of a 364 -day facility which enables borrowing of up to $6,000 and can be renewed for an additional 364 -day period or the company can convert any amounts outstanding into a term loan for a period of up to one year, and a $2,000 five -year facility expiring in December 2020 . These facilities support commercial paper borrowing and can also be used for general corporate purposes. The company’s practice has been to continually replace expiring commitments with new commitments on substantially the same terms, maintaining levels management believes appropriate. Any borrowings under the facilities would be unsecured indebtedness at interest rates based on the London Interbank Offered Rate or an average of base lending rates published by specified banks and on terms reflecting the company’s strong credit rating. No borrowings were outstanding under these facilities at December 31, 2015 . At both December 31, 2015 and 2014 , the company classified $8,000 of short-term debt as long-term. Settlement of these obligations is not expected to require the use of working capital within one year, and the company has both the intent and the ability, as evidenced by committed credit facilities, to refinance them on a long-term basis.

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Total long-term debt, excluding capital leases, at December 31, 2015 , was $33,584 . The company’s long-term debt outstanding at year-end 2015 and 2014 was as follows: At December 31 2015 2014 3.191% notes due 2023 $ 2,250 $ 2,250 Floating rate notes due 2017 (0.555%) 1 2,050 650 1.104% notes due 2017 2,000 2,000 1.718% notes due 2018 2,000 2,000 2.355% notes due 2022 2,000 2,000 1.365% notes due 2018 1,750 — 1.961% notes due 2020 1,750 — 4.95% notes due 2019 1,500 1,500 1.790% notes due 2018 1,250 — 2.419% notes due 2020 1,250 — 1.345% notes due 2017 1,100 1,100 1.344% notes due 2017 1,000 — 2.427% notes due 2020 1,000 1,000 Floating rate notes due 2018 (0.676%) 1 800 — 0.889% notes due 2016 750 750 2.193% notes due 2019 750 750 3.326% notes due 2025 750 — 2.411% notes due 2022 700 — Floating rate notes due 2016 (0.444%) 2 700 700 Floating rate notes due 2019 (0.772%) 2 400 400 Floating rate notes due 2021 (0.892%) 2 400 400 Floating rate notes due 2022 (0.952%) 2 350 — 8.625% debentures due 2032 147 147 Amortizing Bank Loan due 2018 (1.172%) 2 110 — 8.625% debentures due 2031 108 107 8.0% debentures due 2032 74 74 9.75% debentures due 2020 54 54 8.875% debentures due 2021 40 40 Medium-term notes, maturing from 2021 to 2038 (5.975%) 1 38 38 Total including debt due within one year 27,071 15,960 Debt due within one year (1,487 ) — Reclassified from short-term debt 8,000 8,000 Total long-term debt $ 33,584 $ 23,960 1 Weighted-average interest rate at December 31, 2015 . 2 Interest rate at December 31, 2015. Chevron has an automatic shelf registration statement that expires in August 2018. This registration statement is for an unspecified amount of nonconvertible debt securities issued or guaranteed by the company. Long-term debt of $27,071 matures as follows: 2016 – $1,487 ; 2017 – $6,187 ; 2018 – $5,836 ; 2019 – $2,650 ; 2020 – $4,054 ; and after 2020 – $6,857 . The company completed bond issuances of $6,000 and $5,000 in March and November 2015, respectively. See Note 9, beginning on page FS-34, for information concerning the fair value of the company’s long-term debt.

Accounting for Suspended Explor

Accounting for Suspended Exploratory Wells	12 Months Ended
	Dec. 31, 2015
Accounting for Suspended Exploratory Wells [Abstract]
Accounting for Suspended Exploratory Wells	Accounting for Suspended Exploratory Wells The company continues to capitalize exploratory well costs after the completion of drilling when (a) the well has found a sufficient quantity of reserves to justify completion as a producing well, and (b) the business unit is making sufficient progress assessing the reserves and the economic and operating viability of the project. If either condition is not met or if the company obtains information that raises substantial doubt about the economic or operational viability of the project, the exploratory well would be assumed to be impaired, and its costs, net of any salvage value, would be charged to expense. The following table indicates the changes to the company’s suspended exploratory well costs for the three years ended December 31, 2015 : 2015 2014 2013 Beginning balance at January 1 $ 4,195 $ 3,245 $ 2,681 Additions to capitalized exploratory well costs pending the determination of proved reserves 869 1,591 885 Reclassifications to wells, facilities and equipment based on the determination of proved reserves (164 ) (298 ) (290 ) Capitalized exploratory well costs charged to expense (1,397 ) (312 ) (31 ) Other reductions * (191 ) (31 ) — Ending balance at December 31 $ 3,312 $ 4,195 $ 3,245 * Represents property sales. The following table provides an aging of capitalized well costs and the number of projects for which exploratory well costs have been capitalized for a period greater than one year since the completion of drilling. At December 31 2015 2014 2013 Exploratory well costs capitalized for a period of one year or less $ 489 $ 1,522 $ 641 Exploratory well costs capitalized for a period greater than one year 2,823 2,673 2,604 Balance at December 31 $ 3,312 $ 4,195 $ 3,245 Number of projects with exploratory well costs that have been capitalized for a period greater than one year * 39 51 51 * Certain projects have multiple wells or fields or both. Of the $2,823 of exploratory well costs capitalized for more than one year at December 31, 2015 , $1,662 ( 20 projects) is related to projects that had drilling activities under way or firmly planned for the near future. The $1,161 balance is related to 19 projects in areas requiring a major capital expenditure before production could begin and for which additional drilling efforts were not under way or firmly planned for the near future. Additional drilling was not deemed necessary because the presence of hydrocarbons had already been established, and other activities were in process to enable a future decision on project development. The projects for the $1,161 referenced above had the following activities associated with assessing the reserves and the projects’ economic viability: (a) $190 ( two projects) – undergoing front-end engineering and design with final investment decision expected within four years ; (b) $99 ( one project) – development concept under review by government; (c) $814 ( seven projects) – development alternatives under review; (d) $58 ( nine projects) – miscellaneous activities for projects with smaller amounts suspended. While progress was being made on all 39 projects, the decision on the recognition of proved reserves under SEC rules in some cases may not occur for several years because of the complexity, scale and negotiations associated with the projects. Approximately half of these decisions are expected to occur in the next five years . The $2,823 of suspended well costs capitalized for a period greater than one year as of December 31, 2015 , represents 165 exploratory wells in 39 projects. The tables below contain the aging of these costs on a well and project basis: Aging based on drilling completion date of individual wells: Amount Number of wells 1998-2004 $ 285 26 2005-2009 395 33 2010-2014 2,143 106 Total $ 2,823 165 Aging based on drilling completion date of last suspended well in project: Amount Number of projects 2003-2007 $ 200 4 2008-2011 393 6 2012-2015 2,230 29 Total $ 2,823 39

Stock Options and Other Share-B

Stock Options and Other Share-Based Compensation	12 Months Ended
	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Stock Options and Other Share-Based Compensation	Stock Options and Other Share-Based Compensation Compensation expense for stock options for 2015 , 2014 and 2013 was $312 ( $203 after tax), $287 ( $186 after tax) and $292 ( $190 after tax), respectively. In addition, compensation expense for stock appreciation rights, restricted stock, performance units and restricted stock units was $32 ( $21 after tax), $71 ( $46 after tax) and $223 ( $145 after tax) for 2015 , 2014 and 2013 , respectively. No significant stock-based compensation cost was capitalized at December 31, 2015 , or December 31, 2014 . Cash received in payment for option exercises under all share-based payment arrangements for 2015 , 2014 and 2013 was $195 , $527 and $553 , respectively. Actual tax benefits realized for the tax deductions from option exercises were $17 , $54 and $73 for 2015 , 2014 and 2013 , respectively. Cash paid to settle performance units and stock appreciation rights was $104 , $204 and $186 for 2015 , 2014 and 2013 , respectively. Awards under the Chevron Long-Term Incentive Plan (LTIP) may take the form of, but are not limited to, stock options, restricted stock, restricted stock units, stock appreciation rights, performance units and nonstock grants. From April 2004 through May 2023, no more than 260 million shares may be issued under the LTIP. For awards issued on or after May 29, 2013, no more than 50 million of those shares may be in a form other than a stock option, stock appreciation right or award requiring full payment for shares by the award recipient. For the major types of awards outstanding as of December 31, 2015 , the contractual terms vary between three years for the performance units and restricted stock units, and 10 years for the stock options and stock appreciation rights. Remaining awards under the Unocal Share-Based Plans expired in early 2015. The fair market values of stock options and stock appreciation rights granted in 2015 , 2014 and 2013 were measured on the date of grant using the Black-Scholes option-pricing model, with the following weighted-average assumptions: Year ended December 31 2015 2014 2013 Expected term in years 1 6.1 6.0 6.0 Volatility 2 21.9 % 30.3 % 31.3 % Risk-free interest rate based on zero coupon U.S. treasury note 1.4 % 1.9 % 1.2 % Dividend yield 3.6 % 3.3 % 3.3 % Weighted-average fair value per option granted $ 13.89 $ 25.86 $ 24.48 1 Expected term is based on historical exercise and postvesting cancellation data. 2 Volatility rate is based on historical stock prices over an appropriate period, generally equal to the expected term. A summary of option activity during 2015 is presented below: Shares (Thousands) Weighted-Average Exercise Price Averaged Remaining Contractual Term (Years) Aggregate Intrinsic Value Outstanding at January 1, 2015 78,341 $ 93.59 Granted 22,126 $ 103.71 Exercised (3,104 ) $ 62.06 Forfeited (3,071 ) $ 103.70 Outstanding at December 31, 2015 94,292 $ 96.67 5.83 $ 467 Exercisable at December 31, 2015 65,657 $ 91.85 4.61 $ 467 The total intrinsic value (i.e., the difference between the exercise price and the market price) of options exercised during 2015 , 2014 and 2013 was $120 , $398 and $445 , respectively. During this period, the company continued its practice of issuing treasury shares upon exercise of these awards. As of December 31, 2015 , there was $190 of total unrecognized before-tax compensation cost related to nonvested share-based compensation arrangements granted under the plans. That cost is expected to be recognized over a weighted-average period of 1.7 years. At January 1, 2015 , the number of LTIP performance units outstanding was equivalent to 2,265,952 shares. During 2015 , 890,000 units were granted, 828,868 units vested with cash proceeds distributed to recipients and 134,147 units were forfeited. At December 31, 2015 , units outstanding were 2,192,937 . The fair value of the liability recorded for these instruments was $166 , and was measured using the Monte Carlo simulation method. In addition, outstanding stock appreciation rights and other awards that were granted under various LTIP programs totaled approximately 4.5 million equivalent shares as of December 31, 2015 . A liability of $51 was recorded for these awards.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2015
Compensation and Retirement Disclosure [Abstract]
Employee Benefit Plans	Employee Benefit Plans The company has defined benefit pension plans for many employees. The company typically prefunds defined benefit plans as required by local regulations or in certain situations where prefunding provides economic advantages. In the United States, all qualified plans are subject to the Employee Retirement Income Security Act (ERISA) minimum funding standard. The company does not typically fund U.S. nonqualified pension plans that are not subject to funding requirements under laws and regulations because contributions to these pension plans may be less economic and investment returns may be less attractive than the company’s other investment alternatives. The company also sponsors other postretirement benefit (OPEB) plans that provide medical and dental benefits, as well as life insurance for some active and qualifying retired employees. The plans are unfunded, and the company and retirees share the costs. Medical coverage for Medicare-eligible retirees in the company’s main U.S. medical plan is secondary to Medicare (including Part D) and the increase to the company contribution for retiree medical coverage is limited to no more than 4 percent each year. Certain life insurance benefits are paid by the company. The company recognizes the overfunded or underfunded status of each of its defined benefit pension and OPEB plans as an asset or liability on the Consolidated Balance Sheet. The funded status of the company’s pension and OPEB plans for 2015 and 2014 follows: Pension Benefits 2015 2014 Other Benefits U.S. Int’l. U.S. Int’l. 2015 2014 Change in Benefit Obligation Benefit obligation at January 1 $ 14,250 $ 5,767 $ 12,080 $ 6,095 $ 3,660 $ 3,138 Service cost 538 185 450 190 72 50 Interest cost 502 277 494 340 151 148 Plan participants' contributions — 6 — 8 148 150 Plan amendments — (6 ) — 3 — 2 Actuarial (gain) loss (345 ) (309 ) 2,299 336 (326 ) 544 Foreign currency exchange rate changes — (326 ) — (348 ) (37 ) (22 ) Benefits paid (1,382 ) (241 ) (1,073 ) (293 ) (344 ) (350 ) Divestitures — — — (564 ) — — Curtailment — (17 ) — — — — Benefit obligation at December 31 13,563 5,336 14,250 5,767 3,324 3,660 Change in Plan Assets Fair value of plan assets at January 1 11,090 4,244 11,210 4,543 — — Actual return on plan assets (75 ) 112 854 571 — — Foreign currency exchange rate changes — (239 ) — (279 ) — — Employer contributions 641 227 99 276 196 200 Plan participants' contributions — 6 — 8 148 150 Benefits paid (1,382 ) (241 ) (1,073 ) (293 ) (344 ) (350 ) Divestitures — — — (582 ) — — Fair value of plan assets at December 31 10,274 4,109 11,090 4,244 — — Funded Status at December 31 $ (3,289 ) $ (1,227 ) $ (3,160 ) $ (1,523 ) $ (3,324 ) $ (3,660 ) Amounts recognized on the Consolidated Balance Sheet for the company’s pension and OPEB plans at December 31, 2015 and 2014 , include: Pension Benefits 2015 2014 Other Benefits U.S. Int’l. U.S. Int’l. 2015 2014 Deferred charges and other assets $ 13 $ 333 $ 13 $ 244 $ — $ — Accrued liabilities (153 ) (77 ) (123 ) (68 ) (191 ) (198 ) Noncurrent employee benefit plans (3,149 ) (1,483 ) (3,050 ) (1,699 ) (3,133 ) (3,462 ) Net amount recognized at December 31 $ (3,289 ) $ (1,227 ) $ (3,160 ) $ (1,523 ) $ (3,324 ) $ (3,660 ) Amounts recognized on a before-tax basis in “Accumulated other comprehensive loss” for the company’s pension and OPEB plans were $6,478 and $7,417 at the end of 2015 and 2014 , respectively. These amounts consisted of: Pension Benefits 2015 2014 Other Benefits U.S. Int’l. U.S. Int’l. 2015 2014 Net actuarial loss $ 4,809 $ 1,143 $ 4,972 $ 1,487 $ 367 $ 763 Prior service (credit) costs (5 ) 120 (13 ) 150 44 58 Total recognized at December 31 $ 4,804 $ 1,263 $ 4,959 $ 1,637 $ 411 $ 821 The accumulated benefit obligations for all U.S. and international pension plans were $12,032 and $4,684 , respectively, at December 31, 2015 , and $12,833 and $4,995 , respectively, at December 31, 2014 . Information for U.S. and international pension plans with an accumulated benefit obligation in excess of plan assets at December 31, 2015 and 2014 , was: Pension Benefits 2015 2014 U.S. Int’l. U.S. Int’l. Projected benefit obligations $ 13,500 $ 1,623 $ 14,182 $ 1,938 Accumulated benefit obligations 11,969 1,357 12,765 1,525 Fair value of plan assets 10,198 207 11,009 262 The components of net periodic benefit cost and amounts recognized in the Consolidated Statement of Comprehensive Income for 2015 , 2014 and 2013 are shown in the table below: Pension Benefits 2015 2014 2013 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2015 2014 2013 Net Periodic Benefit Cost Service cost $ 538 $ 185 $ 450 $ 190 $ 495 $ 197 $ 72 $ 50 $ 66 Interest cost 502 277 494 340 471 314 151 148 149 Expected return on plan assets (783 ) (262 ) (788 ) (298 ) (701 ) (274 ) — — — Amortization of prior service costs (credits) (8 ) 22 (9 ) 21 2 21 14 14 (50 ) Recognized actuarial losses 356 78 209 96 485 143 34 7 53 Settlement losses 320 6 237 208 173 12 — — — Curtailment losses (gains) — (14 ) — — — — — — — Total net periodic benefit cost 925 292 593 557 925 413 271 219 218 Changes Recognized in Comprehensive Income Net actuarial (gain) loss during period 513 (260 ) 2,233 (17 ) (2,244 ) (476 ) (362 ) 514 (659 ) Amortization of actuarial loss (676 ) (84 ) (446 ) (304 ) (658 ) (155 ) (34 ) (7 ) (53 ) Prior service (credits) costs during period — (6 ) — 4 (78 ) 18 — 2 — Amortization of prior service (costs) credits 8 (24 ) 9 (21 ) (2 ) (21 ) (14 ) (14 ) 50 Total changes recognized in other (155 ) (374 ) 1,796 (338 ) (2,982 ) (634 ) (410 ) 495 (662 ) Recognized in Net Periodic Benefit Cost and Other Comprehensive Income $ 770 $ (82 ) $ 2,389 $ 219 $ (2,057 ) $ (221 ) $ (139 ) $ 714 $ (444 ) Net actuarial losses recorded in “Accumulated other comprehensive loss” at December 31, 2015 , for the company’s U.S. pension, international pension and OPEB plans are being amortized on a straight-line basis over approximately 10 , 10 and 16 years, respectively. These amortization periods represent the estimated average remaining service of employees expected to receive benefits under the plans. These losses are amortized to the extent they exceed 10 percent of the higher of the projected benefit obligation or market-related value of plan assets. The amount subject to amortization is determined on a plan-by-plan basis. During 2016 , the company estimates actuarial losses of $335 , $56 and $19 will be amortized from “Accumulated other comprehensive loss” for U.S. pension, international pension and OPEB plans, respectively. In addition, the company estimates an additional $324 will be recognized from “Accumulated other comprehensive loss” during 2016 related to lump-sum settlement costs from the main U.S. pension plan. The weighted average amortization period for recognizing prior service costs (credits) recorded in “Accumulated other comprehensive loss” at December 31, 2015 , was approximately 4 and 11 years for U.S. and international pension plans, respectively, and 7 years for OPEB plans. During 2016 , the company estimates prior service (credits) costs of $(9) , $15 and $14 will be amortized from “Accumulated other comprehensive loss” for U.S. pension, international pension and OPEB plans, respectively. Assumptions The following weighted-average assumptions were used to determine benefit obligations and net periodic benefit costs for years ended December 31: Pension Benefits 2015 2014 2013 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2015 2014 2013 Assumptions used to determine benefit obligations: Discount rate 4.0 % 5.3 % 3.7 % 5.0 % 4.3 % 5.8 % 4.6 % 4.3 % 4.9 % Rate of compensation increase 4.5 % 4.8 % 4.5 % 5.1 % 4.5 % 5.5 % N/A N/A N/A Assumptions used to determine net periodic benefit cost: Discount rate 3.7 % 5.0 % 4.3 % 5.8 % 3.6 % 5.2 % 4.3 % 4.9 % 4.1 % Expected return on plan assets 7.5 % 6.3 % 7.5 % 6.6 % 7.5 % 6.8 % N/A N/A N/A Rate of compensation increase 4.5 % 5.1 % 4.5 % 5.5 % 4.5 % 5.5 % N/A N/A N/A Expected Return on Plan Assets The company’s estimated long-term rates of return on pension assets are driven primarily by actual historical asset-class returns, an assessment of expected future performance, advice from external actuarial firms and the incorporation of specific asset-class risk factors. Asset allocations are periodically updated using pension plan asset/liability studies, and the company’s estimated long-term rates of return are consistent with these studies. For 2015 , the company used an expected long-term rate of return of 7.5 percent for U.S. pension plan assets, which account for 71 percent of the company’s pension plan assets. In both 2014 and 2013 , the company used a long-term rate of return of 7.5 percent for this plan. The market-related value of assets of the main U.S. pension plan used in the determination of pension expense was based on the market values in the three months preceding the year-end measurement date. Management considers the three -month time period long enough to minimize the effects of distortions from day-to-day market volatility and still be contemporaneous to the end of the year. For other plans, market value of assets as of year-end is used in calculating the pension expense. Discount Rate The discount rate assumptions used to determine the U.S. and international pension and OPEB plan obligations and expense reflect the rate at which benefits could be effectively settled, and are equal to the equivalent single rate resulting from yield curve analysis. This analysis considered the projected benefit payments specific to the company's plans and the yields on high-quality bonds. At December 31, 2015 , the projected cash flows were discounted to the valuation date using the yield curve for the main U.S. pension and OPEB plans. The effective discount rates derived from this analysis were 4.0 percent for the main U.S. pension plan and 4.5 percent for the main U.S. OPEB plan. The discount rates for these plans at the end of 2014 were 3.7 and 4.1 percent , respectively, while in 2013 they were 4.3 and 4.7 percent for these plans, respectively. The company changed the method used to estimate the service and interest costs associated with the company’s main U.S. pension and OPEB plans. In prior years, the service and interest costs were estimated utilizing a single weighted-average discount rate derived from the yield curve used to measure the defined benefit obligations at the beginning of the year. Under the new method, these costs are estimated by applying spot rates along the yield curve to the relevant projected cash flows. The change was made to provide a more precise measurement of the service and interest costs by improving the correlation between projected benefit cash flows and the corresponding spot yield curve rates. This change in accounting estimate is accounted for prospectively beginning with the year ending December 31, 2016. The company does not expect the change to have a material effect on its consolidated financial position or liquidity. Other Benefit Assumptions For the measurement of accumulated postretirement benefit obligation at December 31, 2015 , for the main U.S. OPEB plan, the assumed health care cost-trend rates start with 7.1 percent in 2016 and gradually decline to 4.5 percent for 2025 and beyond. For this measurement at December 31, 2014 , the assumed health care cost-trend rates started with 7 percent in 2015 and gradually declined to 4.5 percent for 2025 and beyond. In both measurements, the annual increase to company contributions was capped at 4 percent . Assumed health care cost-trend rates can have a significant effect on the amounts reported for retiree health care costs. The impact is mitigated by the 4 percent cap on the company’s medical contributions for the main U.S. plan. A 1-percentage-point change in the assumed health care cost-trend rates would have the following effects on worldwide plans: 1 Percent Increase 1 Percent Decrease Effect on total service and interest cost components $ 20 $ (17 ) Effect on postretirement benefit obligation $ 192 $ (164 ) Plan Assets and Investment Strategy The fair value measurements of the company’s pension plans for 2015 and 2014 are below: U.S. Int’l. Total Fair Value Level 1 Level 2 Level 3 Total Fair Value Level 1 Level 2 Level 3 At December 31, 2014 Equities U.S. 1 $ 2,087 $ 2,087 $ — $ — $ 241 $ 241 $ — $ — International 1,297 1,297 — — 313 313 — — Collective Trusts/Mutual Funds 2 3,240 22 3,218 — 979 173 806 — Fixed Income Government 84 47 37 — 1,066 53 1,013 — Corporate 1,502 — 1,502 — 585 26 537 22 Mortgage-Backed Securities 1 — 1 — 1 — 1 — Other Asset Backed — — — — — — — — Collective Trusts/Mutual Funds 2 1,174 — 1,174 — 394 16 378 — Mixed Funds 3 — — — — 122 3 119 — Real Estate 4 1,364 — — 1,364 329 — — 329 Cash and Cash Equivalents 270 270 — — 190 189 1 — Other 5 71 (3 ) 20 54 24 — 21 3 Total at December 31, 2014 $ 11,090 $ 3,720 $ 5,952 $ 1,418 $ 4,244 $ 1,014 $ 2,876 $ 354 At December 31, 2015 Equities U.S. 1 $ 1,699 $ 1,699 $ — $ — $ 392 $ 382 $ 10 $ — International 1,302 1,296 6 — 457 435 22 — Collective Trusts/Mutual Funds 2 2,460 18 2,442 — 572 7 565 — Fixed Income Government 257 46 211 — 1,089 93 996 — Corporate 1,654 — 1,654 — 615 33 557 25 Bank Loans 148 — 148 — — — — — Mortgage-Backed Securities 1 — 1 — 1 — 1 — Other Asset Backed 1 — 1 — — — — — Collective Trusts/Mutual Funds 2 933 — 933 — 269 12 257 — Mixed Funds 3 — — — — 85 4 81 — Real Estate 4 1,494 — — 1,494 378 — — 378 Cash and Cash Equivalents 253 253 — — 232 232 — — Other 5 72 (6 ) 26 52 19 (2 ) 19 2 Total at December 31, 2015 $ 10,274 $ 3,306 $ 5,422 $ 1,546 $ 4,109 $ 1,196 $ 2,508 $ 405 1 U.S. equities include investments in the company’s common stock in the amount of $9 at December 31, 2015 , and $24 at December 31, 2014 . 2 Collective Trusts/Mutual Funds for U.S. plans are entirely index funds; for International plans, they are mostly index funds. For these index funds, the Level 2 designation is partially based on the restriction that advance notification of redemptions, typically two business days, is required. 3 Mixed funds are composed of funds that invest in both equity and fixed-income instruments in order to diversify and lower risk. 4 The year-end valuations of the U.S. real estate assets are based on internal appraisals by the real estate managers, which are updates of third-party appraisals that occur at least once a year for each property in the portfolio. 5 The “Other” asset class includes net payables for securities purchased but not yet settled (Level 1); dividends and interest- and tax-related receivables (Level 2); insurance contracts and investments in private-equity limited partnerships (Level 3). The effects of fair value measurements using significant unobservable inputs on changes in Level 3 plan assets are outlined below: Fixed Income Corporate Mortgage-Backed Securities Real Estate Other Total Total at December 31, 2013 $ 23 $ 2 $ 1,559 $ 57 $ 1,641 Actual Return on Plan Assets: Assets held at the reporting date — — 115 — 115 Assets sold during the period — — 20 — 20 Purchases, Sales and Settlements (1 ) (2 ) (1 ) — (4 ) Transfers in and/or out of Level 3 — — — — — Total at December 31, 2014 $ 22 $ — $ 1,693 $ 57 $ 1,772 Actual Return on Plan Assets: Assets held at the reporting date (3 ) — 149 (1 ) 145 Assets sold during the period — — 23 — 23 Purchases, Sales and Settlements 6 — 7 (2 ) 11 Transfers in and/or out of Level 3 — — — — — Total at December 31, 2015 $ 25 $ — $ 1,872 $ 54 $ 1,951 The primary investment objectives of the pension plans are to achieve the highest rate of total return within prudent levels of risk and liquidity, to diversify and mitigate potential downside risk associated with the investments, and to provide adequate liquidity for benefit payments and portfolio management. The company’s U.S. and U.K. pension plans comprise 91 percent of the total pension assets. Both the U.S. and U.K. plans have an Investment Committee that regularly meets during the year to review the asset holdings and their returns. To assess the plans’ investment performance, long-term asset allocation policy benchmarks have been established. For the primary U.S. pension plan, the company's Benefit Plan Investment Committee has established the following approved asset allocation ranges: Equities 40 – 70 percent , Fixed Income and Cash 20 – 60 percent , Real Estate 0 – 15 percent , and Other 0 – 5 percent . For the U.K. pension plan, the U.K. Board of Trustees has established the following asset allocation guidelines: Equities 30 – 50 percent, Fixed Income and Cash 35 – 65 percent , and Real Estate 5 – 15 percent. The other significant international pension plans also have established maximum and minimum asset allocation ranges that vary by plan. Actual asset allocation within approved ranges is based on a variety of current economic and market conditions and consideration of specific asset class risk. To mitigate concentration and other risks, assets are invested across multiple asset classes with active investment managers and passive index funds. The company does not prefund its OPEB obligations. Cash Contributions and Benefit Payments In 2015 , the company contributed $641 and $227 to its U.S. and international pension plans, respectively. In 2016 , the company expects contributions to be approximately $650 to its U.S. plans and $250 to its international pension plans. Actual contribution amounts are dependent upon investment returns, changes in pension obligations, regulatory environments and other economic factors. Additional funding may ultimately be required if investment returns are insufficient to offset increases in plan obligations. The company anticipates paying OPEB benefits of approximately $191 in 2016 ; $196 was paid in 2015 . The following benefit payments, which include estimated future service, are expected to be paid by the company in the next 10 years: Pension Benefits Other U.S. Int’l. Benefits 2016 $ 1,462 $ 284 $ 191 2017 $ 1,384 $ 297 $ 195 2018 $ 1,360 $ 467 $ 199 2019 $ 1,329 $ 339 $ 203 2020 $ 1,287 $ 346 $ 207 2021-2025 $ 5,804 $ 1,822 $ 1,053 Employee Savings Investment Plan Eligible employees of Chevron and certain of its subsidiaries participate in the Chevron Employee Savings Investment Plan (ESIP). Compensation expense for the ESIP totaled $316 , $316 and $163 in 2015, 2014 and 2013, respectively. The amount for ESIP expense in 2013 is net of $140 , which reflects the value of common stock released from the former leveraged employee stock ownership plan (LESOP). LESOP debt was retired in 2013, and all remaining shares were released. Benefit Plan Trusts Prior to its acquisition by Chevron, Texaco established a benefit plan trust for funding obligations under some of its benefit plans. At year-end 2015 , the trust contained 14.2 million shares of Chevron treasury stock. The trust will sell the shares or use the dividends from the shares to pay benefits only to the extent that the company does not pay such benefits. The company intends to continue to pay its obligations under the benefit plans. The trustee will vote the shares held in the trust as instructed by the trust’s beneficiaries. The shares held in the trust are not considered outstanding for earnings-per-share purposes until distributed or sold by the trust in payment of benefit obligations. Prior to its acquisition by Chevron, Unocal established various grantor trusts to fund obligations under some of its benefit plans, including the deferred compensation and supplemental retirement plans. At December 31, 2015 and 2014 , trust assets of $36 and $38 , respectively, were invested primarily in interest-earning accounts. Employee Incentive Plans The Chevron Incentive Plan is an annual cash bonus plan for eligible employees that links awards to corporate, business unit and individual performance in the prior year. Charges to expense for cash bonuses were $690 , $965 and $871 in 2015 , 2014 and 2013 , respectively. Chevron also has the LTIP for officers and other regular salaried employees of the company and its subsidiaries who hold positions of significant responsibility. Awards under the LTIP consist of stock options and other share-based compensation that are described in Note 22, beginning on page FS-50.

Other Contingencies and Commitm

Other Contingencies and Commitments	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Other Contingencies and Commitments	Other Contingencies and Commitments Income Taxes The company calculates its income tax expense and liabilities quarterly. These liabilities generally are subject to audit and are not finalized with the individual taxing authorities until several years after the end of the annual period for which income taxes have been calculated. Refer to Note 18, beginning on page FS-45, for a discussion of the periods for which tax returns have been audited for the company’s major tax jurisdictions and a discussion for all tax jurisdictions of the differences between the amount of tax benefits recognized in the financial statements and the amount taken or expected to be taken in a tax return. Settlement of open tax years, as well as other tax issues in countries where the company conducts its businesses, are not expected to have a material effect on the consolidated financial position or liquidity of the company and, in the opinion of management, adequate provision has been made for income and franchise taxes for all years under examination or subject to future examination. Guarantees The company’s guarantee of $447 is associated with certain payments under a terminal use agreement entered into by an equity affiliate. Over the approximate 12 -year remaining term of the guarantee, the maximum guarantee amount will be reduced as certain fees are paid by the affiliate. There are numerous cross-indemnity agreements with the affiliate and the other partners to permit recovery of amounts paid under the guarantee. Chevron has recorded no liability for its obligation under this guarantee. Indemnifications In the acquisition of Unocal, the company assumed certain indemnities relating to contingent environmental liabilities associated with assets that were sold in 1997. The acquirer of those assets shared in certain environmental remediation costs up to a maximum obligation of $200 , which had been reached at December 31, 2009. Under the indemnification agreement, after reaching the $200 obligation, Chevron is solely responsible until April 2022, when the indemnification expires. The environmental conditions or events that are subject to these indemnities must have arisen prior to the sale of the assets in 1997. Although the company has provided for known obligations under this indemnity that are probable and reasonably estimable, the amount of additional future costs may be material to results of operations in the period in which they are recognized. The company does not expect these costs will have a material effect on its consolidated financial position or liquidity. Long-Term Unconditional Purchase Obligations and Commitments, Including Throughput and Take-or-Pay Agreements The company and its subsidiaries have certain contingent liabilities with respect to long-term unconditional purchase obligations and commitments, including throughput and take-or-pay agreements, some of which relate to suppliers’ financing arrangements. The agreements typically provide goods and services, such as pipeline and storage capacity, drilling rigs, utilities, and petroleum products, to be used or sold in the ordinary course of the company’s business. The aggregate approximate amounts of required payments under these various commitments are: 2016 – $2,100 ; 2017 – $1,900 ; 2018 – $1,700 ; 2019 – $1,500 ; 2020 – $1,100 ; 2020 and after – $3,100 . A portion of these commitments may ultimately be shared with project partners. Total payments under the agreements were approximately $1,900 in 2015 , $3,700 in 2014 and $3,600 in 2013 . Environmental The company is subject to loss contingencies pursuant to laws, regulations, private claims and legal proceedings related to environmental matters that are subject to legal settlements or that in the future may require the company to take action to correct or ameliorate the effects on the environment of prior release of chemicals or petroleum substances, including MTBE, by the company or other parties. Such contingencies may exist for various operating, closed and divested sites, including, but not limited to, federal Superfund sites and analogous sites under state laws, refineries, chemical plants, marketing facilities, crude oil fields, and mining sites. Although the company has provided for known environmental obligations that are probable and reasonably estimable, it is likely that the company will continue to incur additional liabilities. The amount of additional future costs are not fully determinable due to such factors as the unknown magnitude of possible contamination, the unknown timing and extent of the corrective actions that may be required, the determination of the company’s liability in proportion to other responsible parties, and the extent to which such costs are recoverable from third parties. These future costs may be material to results of operations in the period in which they are recognized, but the company does not expect these costs will have a material effect on its consolidated financial position or liquidity. Chevron’s environmental reserve as of December 31, 2015 , was $1,578 . Included in this balance were $348 related to remediation activities at approximately 163 sites for which the company had been identified as a potentially responsible party under the provisions of the federal Superfund law or analogous state laws which provide for joint and several liability for all responsible parties. Any future actions by regulatory agencies to require Chevron to assume other potentially responsible parties’ costs at designated hazardous waste sites are not expected to have a material effect on the company’s results of operations, consolidated financial position or liquidity. Of the remaining year-end 2015 environmental reserves balance of $1,230 , $845 is related to the company’s U.S. downstream operations, $58 to its international downstream operations, $323 to upstream operations and $4 to other businesses. Liabilities at all sites were primarily associated with the company’s plans and activities to remediate soil or groundwater contamination or both. The company manages environmental liabilities under specific sets of regulatory requirements, which in the United States include the Resource Conservation and Recovery Act and various state and local regulations. No single remediation site at year-end 2015 had a recorded liability that was material to the company’s results of operations, consolidated financial position or liquidity. Refer to Note 25 on page FS-59 for a discussion of the company’s asset retirement obligations. Other Contingencies On November 7, 2011, while drilling a development well in the deepwater Frade Field about 75 miles offshore Brazil, an unanticipated pressure spike caused oil to migrate from the well bore through a series of fissures to the sea floor, emitting approximately 2,400 barrels of oil. The source of the seep was substantially contained within four days and the well was plugged and abandoned. On March 14, 2012, the company identified a small, second seep in a different part of the field. No evidence of any coastal or wildlife impacts related to either of these seeps emerged. As reported in the company’s previously filed periodic reports, it has resolved civil claims relating to these incidents brought by a Brazilian federal district prosecutor. As also reported previously, the federal district prosecutor also filed criminal charges against Chevron and 11 Chevron employees. These charges were dismissed by the trial court on February 19, 2013, reinstated by an appellate court on October 9, 2013, and then, upon Chevron’s motion for reconsideration, dismissed by the appellate court on August 27, 2015. The federal district prosecutor has appealed the appellate court’s decision. Chevron receives claims from and submits claims to customers; trading partners; U.S. federal, state and local regulatory bodies; governments; contractors; insurers; suppliers; and individuals. The amounts of these claims, individually and in the aggregate, may be significant and take lengthy periods to resolve, and may result in gains or losses in future periods. The company and its affiliates also continue to review and analyze their operations and may close, abandon, sell, exchange, acquire or restructure assets to achieve operational or strategic benefits and to improve competitiveness and profitability. These activities, individually or together, may result in significant gains or losses in future periods.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The company records the fair value of a liability for an asset retirement obligation (ARO) as an asset and liability when there is a legal obligation associated with the retirement of a tangible long-lived asset and the liability can be reasonably estimated. The legal obligation to perform the asset retirement activity is unconditional, even though uncertainty may exist about the timing and/or method of settlement that may be beyond the company’s control. This uncertainty about the timing and/or method of settlement is factored into the measurement of the liability when sufficient information exists to reasonably estimate fair value. Recognition of the ARO includes: (1) the present value of a liability and offsetting asset, (2) the subsequent accretion of that liability and depreciation of the asset, and (3) the periodic review of the ARO liability estimates and discount rates. AROs are primarily recorded for the company’s crude oil and natural gas producing assets. No significant AROs associated with any legal obligations to retire downstream long-lived assets have been recognized, as indeterminate settlement dates for the asset retirements prevent estimation of the fair value of the associated ARO. The company performs periodic reviews of its downstream long-lived assets for any changes in facts and circumstances that might require recognition of a retirement obligation. The following table indicates the changes to the company’s before-tax asset retirement obligations in 2015 , 2014 and 2013 : 2015 2014 2013 Balance at January 1 $ 15,053 $ 14,298 $ 13,271 Liabilities incurred 51 133 59 Liabilities settled (981 ) (1,291 ) (907 ) Accretion expense 715 882 627 Revisions in estimated cash flows 804 1,031 1,248 Balance at December 31 $ 15,642 $ 15,053 $ 14,298 In the table above, the amounts associated with "Revisions in estimated cash flows" generally reflect increased cost estimates to abandon wells, equipment and facilities and accelerated timing of abandonment. The long-term portion of the $15,642 balance at the end of 2015 was $14,892 .

Restructuring and Reorganizatio

Restructuring and Reorganization Costs	12 Months Ended
	Dec. 31, 2015
Restructuring and Related Activities [Abstract]
Restructuring and Reorganization Costs	Restructuring and Reorganization Costs In 2015, the company recorded accruals and adjustments for employee reduction programs related to the restructuring and reorganization of its corporate staffs and certain upstream operations. The employee reductions are expected to be substantially completed by the end of 2016. A before-tax charge of $ 353 ($ 223 after-tax) was recorded in 2015, with $ 219 reported as “Operating Expenses” and $ 134 reported as "Selling, general and administrative expense" on the Consolidated Statement of Income. The accrued liability, covering severance benefits, is classified as current on the Consolidated Balance Sheet. Approximately $ 134 ($ 87 after-tax) is associated with employee reductions in All Other, $ 113 ($ 73 after-tax) in U.S. Upstream and $ 106 ($ 63 after-tax) in International Upstream. During 2015, the company made payments of $60 million associated with these liabilities. The following table summarizes the accrued severance liability, which is classified as current on the Consolidated Balance Sheet: Amounts Before Tax Balance at January 1, 2015 $ — Accruals/Adjustments 353 Payments (60 ) Balance at December 31, 2015 $ 293

Other Financial Information

Other Financial Information	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Other Financial Information	Other Financial Information Earnings in 2015 included after-tax gains of approximately $2,300 relating to the sale of nonstrategic properties. Of this amount, approximately $1,800 and $500 related to downstream and upstream, respectively. Earnings in 2014 included after-tax gains of approximately $3,000 relating to the sale of nonstrategic properties, of which approximately $1,800 and $ 1,000 related to upstream and downstream assets, respectively. Earnings in 2015 included after-tax charges of approximately $3,000 for impairments and other asset write-offs related to upstream. Earnings in 2014 included after-tax charges of approximately $1,000 for impairments and other asset write-offs, of which $ 800 was related to upstream and $200 to a mining asset. Other financial information is as follows: Year ended December 31 2015 2014 2013 Total financing interest and debt costs $ 495 $ 358 $ 284 Less: Capitalized interest 495 358 284 Interest and debt expense $ — $ — $ — Research and development expenses $ 601 $ 707 $ 750 Excess of replacement cost over the carrying value of inventories (LIFO method) 3,745 8,135 9,150 LIFO (losses) / profits on inventory drawdowns included in earnings (65 ) 13 14 Foreign currency effects* $ 769 $ 487 $ 474 * Includes $344 , $118 and $244 in 2015 , 2014 and 2013 , respectively, for the company’s share of equity affiliates’ foreign currency effects. The company has $4,588 in goodwill on the Consolidated Balance Sheet related to the 2005 acquisition of Unocal and to the 2011 acquisition of Atlas Energy, Inc. The company tested this goodwill for impairment during 2015 and concluded no impairment was necessary.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2014
Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	Schedule II — Valuation and Qualifying Accounts Year ended December 31 Millions of Dollars 2015 2014 2013 Employee Termination Benefits Balance at January 1 $ 49 $ 14 $ 30 Additions (reductions) charged to expense 342 53 (6 ) Payments (83 ) (18 ) (10 ) Balance at December 31 $ 308 $ 49 $ 14 Allowance for Doubtful Accounts Balance at January 1 $ 194 $ 95 $ 155 Additions to expense 251 119 1 Bad debt write-offs (16 ) (20 ) (61 ) Balance at December 31 $ 429 $ 194 $ 95 Deferred Income Tax Valuation Allowance * Balance at January 1 $ 16,292 $ 17,171 $ 15,443 Additions to deferred income tax expense 1,440 1,192 2,665 Reduction of deferred income tax expense (2,320 ) (2,071 ) (937 ) Balance at December 31 $ 15,412 $ 16,292 $ 17,171 * See also Note 18 to the Consolidated Financial Statements, beginning on page FS-45.

Summary of Significant Accoun37

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
General	General The company’s Consolidated Financial Statements are prepared in accordance with accounting principles generally accepted in the United States of America. These require the use of estimates and assumptions that affect the assets, liabilities, revenues and expenses reported in the financial statements, as well as amounts included in the notes thereto, including discussion and disclosure of contingent liabilities. Although the company uses its best estimates and judgments, actual results could differ from these estimates as future confirming events occur.
Subsidiary and Affiliated Companies	Subsidiary and Affiliated Companies The Consolidated Financial Statements include the accounts of controlled subsidiary companies more than 50 percent-owned and any variable-interest entities in which the company is the primary beneficiary. Undivided interests in oil and gas joint ventures and certain other assets are consolidated on a proportionate basis. Investments in and advances to affiliates in which the company has a substantial ownership interest of approximately 20 percent to 50 percent, or for which the company exercises significant influence but not control over policy decisions, are accounted for by the equity method. As part of that accounting, the company recognizes gains and losses that arise from the issuance of stock by an affiliate that results in changes in the company’s proportionate share of the dollar amount of the affiliate’s equity currently in income. Investments in affiliates are assessed for possible impairment when events indicate that the fair value of the investment may be below the company’s carrying value. When such a condition is deemed to be other than temporary, the carrying value of the investment is written down to its fair value, and the amount of the write-down is included in net income. In making the determination as to whether a decline is other than temporary, the company considers such factors as the duration and extent of the decline, the investee’s financial performance, and the company’s ability and intention to retain its investment for a period that will be sufficient to allow for any anticipated recovery in the investment’s market value. The new cost basis of investments in these equity investees is not changed for subsequent recoveries in fair value. 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 various factors giving rise to the difference. When appropriate, the company’s share of the affiliate’s reported earnings is adjusted quarterly to reflect the difference between these allocated values and the affiliate’s historical book values.
Fair Value Measurements	Fair Value Measurements The three levels of the fair value hierarchy of inputs the company uses to measure the fair value of an asset or a liability are as follows. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Level 3 inputs are inputs that are not observable in the market.
Derivatives	Derivatives The majority of the company’s activity in derivative commodity instruments is intended to manage the financial risk posed by physical transactions. For some of this derivative activity, generally limited to large, discrete or infrequently occurring transactions, the company may elect to apply fair value or cash flow hedge accounting. For other similar derivative instruments, generally because of the short-term nature of the contracts or their limited use, the company does not apply hedge accounting, and changes in the fair value of those contracts are reflected in current income. For the company’s commodity trading activity, gains and losses from derivative instruments are reported in current income. The company may enter into interest rate swaps from time to time as part of its overall strategy to manage the interest rate risk on its debt. Interest rate swaps related to a portion of the company’s fixed-rate debt, if any, may be accounted for as fair value hedges. Interest rate swaps related to floating-rate debt, if any, are recorded at fair value on the balance sheet with resulting gains and losses reflected in income. Where Chevron is a party to master netting arrangements, fair value receivable and payable amounts recognized for derivative instruments executed with the same counterparty are generally offset on the balance sheet.
Short-Term Investments	Short-Term Investments All short-term investments are classified as available for sale and are in highly liquid debt securities. Those investments that are part of the company’s cash management portfolio and have original maturities of three months or less are reported as “Cash equivalents.” Bank time deposits with maturities greater than 90 days are reported as “Time deposits.” The balance of short-term investments is reported as “Marketable securities” and is marked-to-market, with any unrealized gains or losses included in “Other comprehensive income.”
Inventories	Inventories Crude oil, petroleum products and chemicals inventories are generally stated at cost, using a last-in, first-out method. In the aggregate, these costs are below market. “Materials, supplies and other” inventories generally are stated at average cost.
Properties, Plant and Equipment	Properties, Plant and Equipment The successful efforts method is used for crude oil and natural gas exploration and production activities. All costs for development wells, related plant and equipment, proved mineral interests in crude oil and natural gas properties, and related asset retirement obligation (ARO) assets are capitalized. Costs of exploratory wells are capitalized pending determination of whether the wells found proved reserves. Costs of wells that are assigned proved reserves remain capitalized. Costs also are capitalized for exploratory wells that have found crude oil and natural gas reserves even if the reserves cannot be classified as proved when the drilling is completed, provided the exploratory well has found a sufficient quantity of reserves to justify its completion as a producing well and the company is making sufficient progress assessing the reserves and the economic and operating viability of the project. All other exploratory wells and costs are expensed. Refer to Note 21, beginning on page FS-49, for additional discussion of accounting for suspended exploratory well costs. Long-lived assets to be held and used, including proved crude oil and natural gas properties, are assessed for possible impairment by comparing their carrying values with their associated undiscounted, future net before-tax cash flows. Events that can trigger assessments for possible impairments include write-downs of proved reserves based on field performance, significant decreases in the market value of an asset (including changes to the commodity price forecast), significant change in the extent or manner of use of or a physical change in an asset, and a more-likely-than-not expectation that a long-lived asset or asset group will be sold or otherwise disposed of significantly sooner than the end of its previously estimated useful life. Impaired assets are written down to their estimated fair values, generally their discounted, future net before-tax cash flows. For proved crude oil and natural gas properties, the company performs impairment reviews on a country, concession, PSC, development area or field basis, as appropriate. In Downstream, impairment reviews are performed on the basis of a refinery, a plant, a marketing/lubricants area or distribution area, as appropriate. Impairment amounts are recorded as incremental “Depreciation, depletion and amortization” expense. Long-lived assets that are held for sale are evaluated for possible impairment by comparing the carrying value of the asset with its fair value less the cost to sell. If the net book value exceeds the fair value less cost to sell, the asset is considered impaired and adjusted to the lower value. Refer to Note 9, beginning on page FS-34, relating to fair value measurements. The fair value of a liability for an ARO is recorded as an asset and a liability when there is a legal obligation associated with the retirement of a long-lived asset and the amount can be reasonably estimated. Refer also to Note 25, on page FS-59, relating to AROs. Depreciation and depletion of all capitalized costs of proved crude oil and natural gas producing properties, except mineral interests, are expensed using the unit-of-production method, generally by individual field, as the proved developed reserves are produced. Depletion expenses for capitalized costs of proved mineral interests are recognized using the unit-of-production method by individual field as the related proved reserves are produced. Periodic valuation provisions for impairment of capitalized costs of unproved mineral interests are expensed. The capitalized costs of all other plant and equipment are depreciated or amortized over their estimated useful lives. In general, the declining-balance method is used to depreciate plant and equipment in the United States; the straight-line method is generally used to depreciate international plant and equipment and to amortize all capitalized leased assets. Gains or losses are not recognized for normal retirements of properties, plant and equipment subject to composite group amortization or depreciation. Gains or losses from abnormal retirements are recorded as expenses, and from sales as “Other income.” Expenditures for maintenance (including those for planned major maintenance projects), repairs and minor renewals to maintain facilities in operating condition are generally expensed as incurred. Major replacements and renewals are capitalized.
Goodwill	Goodwill Goodwill resulting from a business combination is not subject to amortization. The company tests such goodwill at the reporting unit level for impairment on an annual basis and between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of the reporting unit below its carrying amount.
Environmental Expenditures	Environmental Expenditures Environmental expenditures that relate to ongoing operations or to conditions caused by past operations are expensed. Expenditures that create future benefits or contribute to future revenue generation are capitalized. Liabilities related to future remediation costs are recorded when environmental assessments or cleanups or both are probable and the costs can be reasonably estimated. For crude oil, natural gas and mineral-producing properties, a liability for an ARO is made in accordance with accounting standards for asset retirement and environmental obligations. Refer to Note 25, on page FS-59, for a discussion of the company’s AROs. For federal Superfund sites and analogous sites under state laws, the company records a liability for its designated share of the probable and estimable costs, and probable amounts for other potentially responsible parties when mandated by the regulatory agencies because the other parties are not able to pay their respective shares. The gross amount of environmental liabilities is based on the company’s best estimate of future costs using currently available technology and applying current regulations and the company’s own internal environmental policies. Future amounts are not discounted. Recoveries or reimbursements are recorded as assets when receipt is reasonably assured.
Currency Translation	Currency Translation The U.S. dollar is the functional currency for substantially all of the company’s consolidated operations and those of its equity affiliates. For those operations, all gains and losses from currency remeasurement are included in current period income. The cumulative translation effects for those few entities, both consolidated and affiliated, using functional currencies other than the U.S. dollar are included in “Currency translation adjustment” on the Consolidated Statement of Equity.
Revenue Recognition	Revenue Recognition Revenues associated with sales of crude oil, natural gas, petroleum and chemicals products, and all other sources are recorded when title passes to the customer, net of royalties, discounts and allowances, as applicable. Revenues from natural gas production from properties in which Chevron has an interest with other producers are generally recognized using the entitlement method. Excise, value-added and similar taxes assessed by a governmental authority on a revenue-producing transaction between a seller and a customer are presented on a gross basis. The associated amounts are shown as a footnote to the Consolidated Statement of Income, on page FS-23. Purchases and sales of inventory with the same counterparty that are entered into in contemplation of one another (including buy/sell arrangements) are combined and recorded on a net basis and reported in “Purchased crude oil and products” on the Consolidated Statement of Income.
Stock Options and Other Share-Based Compensation	Stock Options and Other Share-Based Compensation The company issues stock options and other share-based compensation to certain employees. For equity awards, such as stock options, total compensation cost is based on the grant date fair value, and for liability awards, such as stock appreciation rights, total compensation cost is based on the settlement value. The company recognizes stock-based compensation expense for all awards over the service period required to earn the award, which is the shorter of the vesting period or the time period an employee becomes eligible to retain the award at retirement. Stock options and stock appreciation rights granted under the company’s Long-Term Incentive Plan have graded vesting provisions by which one-third of each award vests on the first, second and third anniversaries of the date of grant. The company amortizes these graded awards on a straight-line basis.
Noncontrolling Interests	Noncontrolling Interests Ownership interests in the company’s subsidiaries held by parties other than the parent are presented separately from the parent’s equity on the Consolidated Balance Sheet. The amount of consolidated net income attributable to the parent and the noncontrolling interests are both presented on the face of the Consolidated Statement of Income. The term “earnings” is defined as “Net Income Attributable to Chevron Corporation.”
Segment Reporting	Although each subsidiary of Chevron is responsible for its own affairs, Chevron Corporation manages its investments in these subsidiaries and their affiliates. The investments are grouped into two business segments, Upstream and Downstream, representing the company’s “reportable segments” and “operating segments.” Upstream operations consist primarily of exploring for, developing and producing crude oil and natural gas; liquefaction, transportation and regasification associated with liquefied natural gas (LNG); transporting crude oil by major international oil export pipelines; processing, transporting, storage and marketing of natural gas; and a gas-to-liquids plant. Downstream operations consist primarily of refining of crude oil into petroleum products; marketing of crude oil and refined products; transporting of crude oil and refined products by pipeline, marine vessel, motor equipment and rail car; and manufacturing and marketing of commodity petrochemicals, plastics for industrial uses, and fuel and lubricant additives. All Other activities of the company include worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities, and technology companies.
Uncertain Income Tax Positions	Uncertain Income Tax Positions The company recognizes a tax benefit in the financial statements for an uncertain tax position only if management’s assessment is that the position is “more likely than not” (i.e., a likelihood greater than 50 percent ) to be allowed by the tax jurisdiction based solely on the technical merits of the position. The term “tax position” in the accounting standards for income taxes refers to a position in a previously filed tax return or a position expected to be taken in a future tax return that is reflected in measuring current or deferred income tax assets and liabilities for interim or annual periods.
Accounting for Suspended Exploratory Wells	Accounting for Suspended Exploratory Wells The company continues to capitalize exploratory well costs after the completion of drilling when (a) the well has found a sufficient quantity of reserves to justify completion as a producing well, and (b) the business unit is making sufficient progress assessing the reserves and the economic and operating viability of the project. If either condition is not met or if the company obtains information that raises substantial doubt about the economic or operational viability of the project, the exploratory well would be assumed to be impaired, and its costs, net of any salvage value, would be charged to expense.

Changes in Accumulated Other 38

Changes in Accumulated Other Comprehensive Losses (Tables)	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss)	The change in Accumulated Other Comprehensive Losses (AOCL) presented on the Consolidated Balance Sheet and the impact of significant amounts reclassified from AOCL on information presented in the Consolidated Statement of Income for the year ending December 31, 2015 , are reflected in the table below. Year Ended December 31, 2015 1 Currency Translation Adjustment Unrealized Holding Gains (Losses) on Securities Derivatives Defined Benefit Plans Total Balance at January 1 $ (96 ) $ (8 ) $ (2 ) $ (4,753 ) $ (4,859 ) Components of Other Comprehensive Income (Loss): Before Reclassifications (44 ) (21 ) — 126 61 Reclassifications 2 — — — 507 507 Net Other Comprehensive Income (Loss) (44 ) (21 ) — 633 568 Balance at December 31 $ (140 ) $ (29 ) $ (2 ) $ (4,120 ) $ (4,291 ) 1 All amounts are net of tax. 2 Refer to Note 23 beginning on page FS-51, for reclassified components totaling $824 that are included in employee benefit costs for the year ending December 31, 2015 . Related income taxes for the same period, totaling $317 , are reflected in Income Tax Expense on the Consolidated Statement of Income. All other reclassified amounts were insignificant.

Noncontrolling Interests (Table

Noncontrolling Interests (Tables)	12 Months Ended
	Dec. 31, 2015
Noncontrolling Interest [Abstract]
Activity for equity attributable to noncontrolling interests	Activity for the equity attributable to noncontrolling interests for 2015 , 2014 and 2013 is as follows: 2015 2014 2013 Balance at January 1 $ 1,163 $ 1,314 $ 1,308 Net income 123 69 174 Distributions to noncontrolling interests (128 ) (47 ) (99 ) Other changes, net 12 (173 ) (69 ) Balance at December 31 $ 1,170 $ 1,163 $ 1,314

Information Relating to the C40

Information Relating to the Consolidated Statement of Cash Flows (Tables)	12 Months Ended
	Dec. 31, 2015
Supplemental Cash Flow Elements [Abstract]
Schedule of information relating to the consolidated statement of cash flows	Year ended December 31 2015 2014 2013 Net increase in operating working capital was composed of the following: Decrease (increase) in accounts and notes receivable $ 3,631 $ 4,491 $ (1,101 ) Decrease (increase) in inventories 85 (146 ) (237 ) Decrease (increase) in prepaid expenses and other current assets 713 (407 ) 834 (Decrease) increase in accounts payable and accrued liabilities (5,769 ) (3,737 ) 160 Decrease in income and other taxes payable (639 ) (741 ) (987 ) Net increase in operating working capital $ (1,979 ) $ (540 ) $ (1,331 ) Net cash provided by operating activities includes the following cash payments for income taxes: Income taxes $ 4,645 $ 10,562 $ 12,898 Net sales (purchases) of marketable securities consisted of the following gross amounts: Marketable securities purchased $ (6 ) $ (162 ) $ (7 ) Marketable securities sold 128 14 10 Net sales (purchases) of marketable securities $ 122 $ (148 ) $ 3 Net maturities of time deposits consisted of the following gross amounts: Investments in time deposits $ — $ (317 ) $ (2,317 ) Maturities of time deposits 8 317 3,017 Net maturities of time deposits $ 8 $ — $ 700 Net (repayments) borrowings of short-term obligations consisted of the following gross and net amounts: Proceeds from issuances of short-term obligations $ 13,805 $ 9,070 $ 1,551 Repayments of short-term obligations (16,379 ) (4,612 ) (375 ) Net borrowings (repayments) of short-term obligations with three months or less maturity 2,239 (1,027 ) 1,202 Net (repayments) borrowings of short-term obligations $ (335 ) $ 3,431 $ 2,378
Capital expenditures	The major components of “Capital expenditures” and the reconciliation of this amount to the reported capital and exploratory expenditures, including equity affiliates, are presented in the following table: Year ended December 31 2015 2014 2013 Additions to properties, plant and equipment * $ 28,213 $ 34,393 $ 36,550 Additions to investments 555 526 934 Current-year dry hole expenditures 736 504 594 Payments for other liabilities and assets, net — (16 ) (93 ) Capital expenditures 29,504 35,407 37,985 Expensed exploration expenditures 1,031 1,110 1,178 Assets acquired through capital lease obligations and other financing obligations 47 332 16 Capital and exploratory expenditures, excluding equity affiliates 30,582 36,849 39,179 Company's share of expenditures by equity affiliates 3,397 3,467 2,698 Capital and exploratory expenditures, including equity affiliates $ 33,979 $ 40,316 $ 41,877 * Excludes noncash additions of $1,362 in 2015 , $2,310 in 2014 and $1,661 in 2013 .

Lease Commitments (Tables)

Lease Commitments (Tables)	12 Months Ended
	Dec. 31, 2015
Leases [Abstract]
Schedule of capitalized leased assets	Details of the capitalized leased assets are as follows: At December 31 2015 2014 Upstream $ 800 $ 765 Downstream 98 97 All Other — — Total 898 862 Less: Accumulated amortization 448 381 Net capitalized leased assets $ 450 $ 481
Rental expenses incurred for operating leases	Rental expenses incurred for operating leases during 2015 , 2014 and 2013 were as follows: Year ended December 31 2015 2014 2013 Minimum rentals $ 1,041 $ 1,080 $ 1,049 Contingent rentals 2 1 1 Total 1,043 1,081 1,050 Less: Sublease rental income 9 14 25 Net rental expense $ 1,034 $ 1,067 $ 1,025
Estimated future minimum lease payments (net of noncancelable sublease rentals) under operating and capital leases	At December 31, 2015 , the estimated future minimum lease payments (net of noncancelable sublease rentals) under operating and capital leases, which at inception had a noncancelable term of more than one year, were as follows: At December 31 Operating Leases Capital Leases Year 2016 $ 846 $ 23 2017 689 21 2018 554 19 2019 420 19 2020 311 6 Thereafter 528 62 Total $ 3,348 $ 150 Less: Amounts representing interest and executory costs $ (53 ) Net present values 97 Less: Capital lease obligations included in short-term debt (17 ) Long-term capital lease obligations $ 80

Summarized Financial Data - C42

Summarized Financial Data - Chevron U.S.A. Inc. (Tables)	12 Months Ended
	Dec. 31, 2015
Summarized Financial Data of Subsidiary One [Abstract]
Summarized Financial Data - Chevron U.S.A. Inc.	The summarized financial information for CUSA and its consolidated subsidiaries is as follows: Year ended December 31 2015 2014 2013 Sales and other operating revenues $ 97,766 $ 157,198 $ 174,318 Total costs and other deductions 101,565 153,139 169,984 Net income (loss) attributable to CUSA (1,054 ) 3,849 3,714
Summarized Financial Data and its Subsidiary	2015 2014 Current assets $ 9,732 $ 13,724 Other assets 59,170 62,195 Current liabilities 13,664 16,191 Other liabilities 29,100 30,175 Total CUSA net equity $ 26,138 $ 29,553 Memo: Total debt $ 14,462 $ 14,473

Summarized Financial Data - T43

Summarized Financial Data - Tengizchevroil LLP (Tables)	12 Months Ended
	Dec. 31, 2015
Summarized Financial Data of Affiliate [Abstract]
Summarized Financial Data - Tengizchevroil LLP	Summarized financial information for 100 percent of TCO is presented in the table below: Year ended December 31 2015 2014 2013 Sales and other operating revenues $ 12,811 $ 22,813 $ 25,239 Costs and other deductions 7,257 10,275 11,173 Net income attributable to TCO 3,897 8,772 9,855
Summarized Financial Data and its Affiliate	At December 31 2015 2014 Current assets $ 2,098 $ 3,425 Other assets 17,094 14,810 Current liabilities 1,063 1,531 Other liabilities 2,266 2,375 Total TCO net equity $ 15,863 $ 14,329

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Assets and Liabilities Measured at Fair Value on a Recurring Basis	Assets and Liabilities Measured at Fair Value on a Recurring Basis At Dec ember 31, 2015 At December 31, 2014 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Marketable securities $ 310 $ 310 $ — $ — $ 422 $ 422 $ — $ — Derivatives 205 189 16 — 413 394 19 — Total Assets at Fair Value $ 515 $ 499 $ 16 $ — $ 835 $ 816 $ 19 $ — Derivatives 53 47 6 — 84 83 1 — Total Liabilities at Fair Value $ 53 $ 47 $ 6 $ — $ 84 $ 83 $ 1 $ —
Assets and Liabilities Measured at Fair Value on a Non-Recurring Basis	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis At December 31 At December 31 Before-Tax Loss Before-Tax Loss Total Level 1 Level 2 Level 3 Year 2015 Total Level 1 Level 2 Level 3 Year 2014 Properties, plant and equipment, net (held and used) $ 3,051 $ — $ 239 $ 2,812 $ 3,222 $ 947 $ — $ 213 $ 734 $ 1,249 Properties, plant and equipment, net (held for sale) 937 — 937 — 844 — — — — 25 Investments and advances 75 — 75 — 28 11 — — 11 41 Total Nonrecurring Assets at Fair Value $ 4,063 $ — $ 1,251 $ 2,812 $ 4,094 $ 958 $ — $ 213 $ 745 $ 1,315

Financial and Derivative Inst45

Financial and Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Consolidated Balance Sheet: Fair Value of Derivatives not Designated as Hedging Instruments	Consolidated Balance Sheet: Fair Value of Derivatives Not Designated as Hedging Instruments At December 31 Type of Contract Balance Sheet Classification 2015 2014 Commodity Accounts and notes receivable, net $ 200 $ 401 Commodity Long-term receivables, net 5 12 Total Assets at Fair Value $ 205 $ 413 Commodity Accounts payable $ 51 $ 57 Commodity Deferred credits and other noncurrent obligations 2 27 Total Liabilities at Fair Value $ 53 $ 84
Consolidated Statement of Income: The Effect of Derivatives not Designated as Hedging Instruments	Consolidated Statement of Income: The Effect of Derivatives Not Designated as Hedging Instruments Gain/(Loss) Type of Derivative Statement of Year ended December 31 Contract Income Classification 2015 2014 2013 Commodity Sales and other operating revenues $ 277 $ 553 $ (108 ) Commodity Purchased crude oil and products 30 (17 ) (77 ) Commodity Other income (3 ) (32 ) (9 ) $ 304 $ 504 $ (194 )
Consolidated Balance Sheet: The Effect of Netting Derivative Assets and Liabilities	The table below represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at December 31, 2015 and December 31, 2014 . Consolidated Balance Sheet: The Effect of Netting Derivative Assets and Liabilities Gross Amount Recognized Gross Amounts Offset Net Amounts Presented Gross Amounts Not Offset Net Amount At December 31, 2015 Derivative Assets $ 2,459 $ 2,254 $ 205 $ — $ 205 Derivative Liabilities $ 2,307 $ 2,254 $ 53 $ — $ 53 At December 31, 2014 Derivative Assets $ 4,004 $ 3,591 $ 413 $ 7 $ 406 Derivative Liabilities $ 3,675 $ 3,591 $ 84 $ — $ 84

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Computation of basic and diluted EPS	Year ended December 31 2015 2014 2013 Basic EPS Calculation Earnings available to common stockholders - Basic * $ 4,587 $ 19,241 $ 21,423 Weighted-average number of common shares outstanding 1,867 1,883 1,916 Add: Deferred awards held as stock units 1 1 1 Total weighted-average number of common shares outstanding 1,868 1,884 1,917 Earnings per share of common stock - Basic $ 2.46 $ 10.21 $ 11.18 Diluted EPS Calculation Earnings available to common stockholders - Diluted * $ 4,587 $ 19,241 $ 21,423 Weighted-average number of common shares outstanding 1,867 1,883 1,916 Add: Deferred awards held as stock units 1 1 1 Add: Dilutive effect of employee stock-based awards 7 14 15 Total weighted-average number of common shares outstanding 1,875 1,898 1,932 Earnings per share of common stock - Diluted $ 2.45 $ 10.14 $ 11.09 * There was no effect of dividend equivalents paid on stock units or dilutive impact of employee stock-based awards on earnings.

Operating Segments and Geogra47

Operating Segments and Geographic Data (Tables)	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Segment Earnings	Earnings by major operating area are presented in the following table: Year ended December 31 2015 2014 2013 Upstream United States $ (4,055 ) $ 3,327 $ 4,044 International 2,094 13,566 16,765 Total Upstream (1,961 ) 16,893 20,809 Downstream United States 3,182 2,637 787 International 4,419 1,699 1,450 Total Downstream 7,601 4,336 2,237 Total Segment Earnings 5,640 21,229 23,046 All Other Interest income 65 77 80 Other (1,118 ) (2,065 ) (1,703 ) Net Income Attributable to Chevron Corporation $ 4,587 $ 19,241 $ 21,423
Segment Assets	Assets at year-end 2015 and 2014 are as follows: At December 31 2015 2014 1 Upstream United States $ 46,407 $ 49,343 International 163,217 152,736 Goodwill 4,588 4,593 Total Upstream 214,212 206,672 Downstream United States 21,408 23,068 International 14,982 17,723 Total Downstream 36,390 40,791 Total Segment Assets 250,602 247,463 All Other United States 5,076 6,603 International 10,425 11,960 Total All Other 15,501 18,563 Total Assets – United States 72,891 79,014 Total Assets – International 188,624 182,419 Goodwill 4,588 4,593 Total Assets $ 266,103 $ 266,026 1 2014 conformed to 2015 presentation
Segment Sales and Other Operating Revenues	Year ended December 31 2015 2014 2013 Upstream United States $ 4,117 $ 7,455 $ 8,052 Intersegment 8,631 15,455 16,865 Total United States 12,748 22,910 24,917 International 15,587 23,808 17,607 Intersegment 11,492 23,107 33,034 Total International 27,079 46,915 50,641 Total Upstream * 39,827 69,825 75,558 Downstream United States 48,420 73,942 80,272 Excise and similar taxes 4,426 4,633 4,792 Intersegment 26 31 39 Total United States 52,872 78,606 85,103 International 54,296 86,848 105,373 Excise and similar taxes 2,933 3,553 3,699 Intersegment 1,528 8,839 859 Total International 58,757 99,240 109,931 Total Downstream * 111,629 177,846 195,034 All Other United States 141 252 358 Intersegment 1,372 1,475 1,524 Total United States 1,513 1,727 1,882 International 5 3 3 Intersegment 37 28 31 Total International 42 31 34 Total All Other 1,555 1,758 1,916 Segment Sales and Other Operating Revenues United States 67,133 103,243 111,902 International 85,878 146,186 160,606 Total Segment Sales and Other Operating Revenues 153,011 249,429 272,508 Elimination of intersegment sales (23,086 ) (48,935 ) (52,352 ) Total Sales and Other Operating Revenues $ 129,925 $ 200,494 $ 220,156 * Effective January 1, 2014, International Upstream prospectively includes selected amounts previously recognized in International Downstream, which are not material to the segments.
Segment income tax expense	Segment income tax expense for the years 2015 , 2014 and 2013 is as follows: Year ended December 31 2015 2014 2013 Upstream United States $ (2,041 ) $ 2,043 $ 2,333 International 1,214 9,217 12,470 Total Upstream (827 ) 11,260 14,803 Downstream United States 1,320 1,302 364 International 1,313 467 389 Total Downstream 2,633 1,769 753 All Other (1,674 ) (1,137 ) (1,248 ) Total Income Tax Expense $ 132 $ 11,892 $ 14,308

Investments and Advances (Table

Investments and Advances (Tables)	12 Months Ended
	Dec. 31, 2015
Investments in and Advances to Affiliates, Schedule of Investments [Abstract]
Equity in earnings, together with investments in and advances to companies accounted for using the equity method and other investments accounted for at or below cost	Equity in earnings, together with investments in and advances to companies accounted for using the equity method and other investments accounted for at or below cost, is shown in the following table. For certain equity affiliates, Chevron pays its share of some income taxes directly. For such affiliates, the equity in earnings does not include these taxes, which are reported on the Consolidated Statement of Income as “Income tax expense.” Investments and Advances Equity in Earnings At December 31* Year ended December 31 2015 2014 2015 2014 2013 Upstream Tengizchevroil $ 8,077 $ 7,319 $ 1,939 $ 4,392 $ 4,957 Petropiar 679 794 180 26 339 Caspian Pipeline Consortium 1,342 1,487 162 191 113 Petroboscan 1,163 917 219 186 300 Angola LNG Limited 3,284 3,277 (417 ) (311 ) (111 ) Other 2,158 2,316 135 229 214 Total Upstream 16,703 16,110 2,218 4,713 5,812 Downstream GS Caltex Corporation 3,620 2,867 824 420 132 Chevron Phillips Chemical Company LLC 5,196 5,116 1,367 1,606 1,371 Caltex Australia Ltd. — 1,161 92 183 224 Other 1,077 1,048 186 180 199 Total Downstream 9,893 10,192 2,469 2,389 1,926 All Other Other (18 ) 33 (3 ) (4 ) (211 ) Total equity method $ 26,578 $ 26,335 $ 4,684 $ 7,098 $ 7,527 Other at or below cost 532 577 Total investments and advances $ 27,110 $ 26,912 Total United States $ 6,863 $ 6,787 $ 1,342 $ 1,623 $ 1,294 Total International $ 20,247 $ 20,125 $ 3,342 $ 5,475 $ 6,233 * 2014 conformed to 2015 presentation
Summarized financial information on a 100 percent basis for all equity affiliates as well as Chevron's total share, which includes Chevron loans to affiliates	The following table provides summarized financial information on a 100 percent basis for all equity affiliates as well as Chevron’s total share, which includes Chevron's net loans to affiliates of $410 , $874 and $1,129 at December 31, 2015 , 2014 and 2013 , respectively. Affiliates Chevron Share Year ended December 31 2015 2014 2013 2015 2014 2013 Total revenues $ 71,389 $ 123,003 $ 131,875 $ 33,492 $ 58,937 $ 63,101 Income before income tax expense 13,129 20,609 24,075 6,279 9,968 11,108 Net income attributable to affiliates 10,649 14,758 15,594 4,691 7,237 7,845 At December 31 Current assets $ 27,162 $ 35,662 $ 39,713 $ 10,657 $ 13,465 $ 15,156 Noncurrent assets 71,650 70,817 68,593 26,607 26,053 25,059 Current liabilities 20,559 25,308 29,642 7,351 9,588 11,587 Noncurrent liabilities 18,560 17,983 19,442 3,909 4,211 4,559 Total affiliates' net equity $ 59,693 $ 63,188 $ 59,222 $ 26,004 $ 25,719 $ 24,069

Properties, Plant and Equipme49

Properties, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Properties, Plant and Equipment	At December 31 Year ended December 31 Gross Investment at Cost Net Investment Additions at Cost 2 Depreciation Expense 3 2015 2014 2013 2015 2014 2013 2015 2014 2013 2015 2014 2013 Upstream United States $ 93,848 $ 96,850 $ 89,555 $ 43,125 $ 45,864 $ 41,831 $ 6,586 $ 9,688 $ 8,188 $ 8,545 $ 5,127 $ 4,412 International 208,395 192,637 169,623 127,459 118,926 104,100 19,993 24,920 27,383 10,803 9,688 8,336 Total Upstream 302,243 289,487 259,178 170,584 164,790 145,931 26,579 34,608 35,571 19,348 14,815 12,748 Downstream United States 23,202 22,640 22,407 10,807 11,019 11,481 696 588 1,154 878 886 780 International 9,177 9,334 9,303 4,090 4,219 4,139 365 530 653 355 396 360 Total Downstream 32,379 31,974 31,710 14,897 15,238 15,620 1,061 1,118 1,807 1,233 1,282 1,140 All Other United States 5,500 5,673 5,402 2,859 3,077 3,194 357 581 721 439 680 286 International 155 155 143 56 68 84 5 25 23 17 16 12 Total All Other 5,655 5,828 5,545 2,915 3,145 3,278 362 606 744 456 696 298 Total United States 122,550 125,163 117,364 56,791 59,960 56,506 7,639 10,857 10,063 9,862 6,693 5,478 Total International 217,727 202,126 179,069 131,605 123,213 108,323 20,363 25,475 28,059 11,175 10,100 8,708 Total $ 340,277 $ 327,289 $ 296,433 $ 188,396 $ 183,173 $ 164,829 $ 28,002 $ 36,332 $ 38,122 $ 21,037 $ 16,793 $ 14,186 1 Other than the United States, Australia and Nigeria, no other country accounted for 10 percent or more of the company’s net properties, plant and equipment (PP&E) in 2015 . Australia had $49,205 , $41,012 and $31,464 in 2015 , 2014 , and 2013 , respectively. Nigeria had PP&E of $18,773 , $19,214 and $18,429 for 2015 , 2014 and 2013 , respectively. 2 Net of dry hole expense related to prior years’ expenditures of $1,573 , $371 and $89 in 2015 , 2014 and 2013 , respectively. 3 Depreciation expense includes accretion expense of $715 , $882 and $627 in 2015 , 2014 and 2013 , respectively, and impairments of $4,066 , $1,274 and $382 in 2015 , 2014 and 2013 , respectively.

Taxes (Tables)

Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Taxes on income	Income Taxes Year ended December 31 2015 2014 2013 Income tax expense (benefit) U.S. federal Current $ (817 ) $ 748 $ 15 Deferred (580 ) 1,330 1,128 State and local Current (187 ) 336 120 Deferred (109 ) 36 74 Total United States (1,693 ) 2,450 1,337 International Current 2,997 9,235 12,296 Deferred (1,172 ) 207 675 Total International 1,825 9,442 12,971 Total income tax expense (benefit) $ 132 $ 11,892 $ 14,308
Reconciliation between the U.S. statutory federal income tax rate and the company's effective income tax rate	The reconciliation between the U.S. statutory federal income tax rate and the company’s effective income tax rate is detailed in the following table: Year ended December 31 2015 2014 2013 U.S. statutory federal income tax rate 35.0 % 35.0 % 35.0 % Effect of income taxes from international operations 1 (25.1 ) 2.1 4.4 State and local taxes on income, net of U.S. federal income tax benefit (1.5 ) 0.7 0.6 Tax credits (0.7 ) (0.2 ) (0.5 ) Other 1,2 (5.0 ) 0.5 0.4 Effective tax rate 2.7 % 38.1 % 39.9 % 1 2013 and 2014 conformed to 2015 presentation. 2 2015 includes one-time tax benefits associated with changes in uncertain tax positions and provision-to-return adjustments.
Composition of deferred tax balances	The reported deferred tax balances are composed of the following: At December 31 2015 2014 Deferred tax liabilities Properties, plant and equipment $ 27,044 $ 28,452 Investments and other 3,743 3,059 Total deferred tax liabilities 30,787 31,511 Deferred tax assets Foreign tax credits (10,534 ) (11,867 ) Abandonment/environmental reserves (6,880 ) (6,686 ) Employee benefits (4,801 ) (4,831 ) Deferred credits (1,810 ) (1,828 ) Tax loss carryforwards (2,748 ) (1,747 ) Other accrued liabilities (525 ) (498 ) Inventory (120 ) (153 ) Miscellaneous (2,525 ) (2,128 ) Total deferred tax assets (29,943 ) (29,738 ) Deferred tax assets valuation allowance 15,412 16,292 Total deferred taxes, net $ 16,256 $ 18,065
Classification of deferred taxes	At December 31, 2015 and 2014 , deferred taxes were classified on the Consolidated Balance Sheet as follows: At December 31 2015 2014 Prepaid expenses and other current assets $ (917 ) $ (1,071 ) Deferred charges and other assets (4,512 ) (3,597 ) Federal and other taxes on income 996 813 Noncurrent deferred income taxes 20,689 21,920 Total deferred income taxes, net $ 16,256 $ 18,065
Changes to the Company's unrecognized tax benefits	The following table indicates the changes to the company’s unrecognized tax benefits for the years ended December 31, 2015 , 2014 and 2013 . The term “unrecognized tax benefits” in the accounting standards for income taxes refers to the differences between a tax position taken or expected to be taken in a tax return and the benefit measured and recognized in the financial statements. Interest and penalties are not included. 2015 2014 2013 Balance at January 1 $ 3,552 $ 3,848 $ 3,071 Foreign currency effects (27 ) (25 ) (58 ) Additions based on tax positions taken in current year 154 354 276 Additions/reductions resulting from current-year asset acquisitions/sales — (22 ) — Additions for tax positions taken in prior years 218 37 1,164 Reductions for tax positions taken in prior years (678 ) (561 ) (176 ) Settlements with taxing authorities in current year (5 ) (50 ) (320 ) Reductions as a result of a lapse of the applicable statute of limitations (172 ) (29 ) (109 ) Balance at December 31 $ 3,042 $ 3,552 $ 3,848
Taxes other than on income	Year ended December 31 2015 2014 2013 United States Excise and similar taxes on products and merchandise $ 4,426 $ 4,633 $ 4,792 Import duties and other levies 4 6 4 Property and other miscellaneous taxes 1,367 1,002 1,036 Payroll taxes 270 273 255 Taxes on production 157 349 333 Total United States 6,224 6,263 6,420 International Excise and similar taxes on products and merchandise 2,933 3,553 3,700 Import duties and other levies 40 45 41 Property and other miscellaneous taxes 2,548 2,277 2,486 Payroll taxes 161 172 168 Taxes on production 124 230 248 Total International 5,806 6,277 6,643 Total taxes other than on income $ 12,030 $ 12,540 $ 13,063

Short-Term Debt (Tables)

Short-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Short-Term Debt	At December 31 2015 2014 Commercial paper * $ 8,252 $ 8,506 Notes payable to banks and others with originating terms of one year or less 20 104 Current maturities of long-term debt 1,487 — Current maturities of long-term capital leases 17 22 Redeemable long-term obligations Long-term debt 3,152 3,152 Capital leases — 6 Subtotal 12,928 11,790 Reclassified to long-term debt (8,000 ) (8,000 ) Total short-term debt $ 4,928 $ 3,790 * Weighted-average interest rates at December 31, 2015 and 2014 , were 0.26 percent and 0.12 percent , respectively.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Long-term debt outstanding	The company’s long-term debt outstanding at year-end 2015 and 2014 was as follows: At December 31 2015 2014 3.191% notes due 2023 $ 2,250 $ 2,250 Floating rate notes due 2017 (0.555%) 1 2,050 650 1.104% notes due 2017 2,000 2,000 1.718% notes due 2018 2,000 2,000 2.355% notes due 2022 2,000 2,000 1.365% notes due 2018 1,750 — 1.961% notes due 2020 1,750 — 4.95% notes due 2019 1,500 1,500 1.790% notes due 2018 1,250 — 2.419% notes due 2020 1,250 — 1.345% notes due 2017 1,100 1,100 1.344% notes due 2017 1,000 — 2.427% notes due 2020 1,000 1,000 Floating rate notes due 2018 (0.676%) 1 800 — 0.889% notes due 2016 750 750 2.193% notes due 2019 750 750 3.326% notes due 2025 750 — 2.411% notes due 2022 700 — Floating rate notes due 2016 (0.444%) 2 700 700 Floating rate notes due 2019 (0.772%) 2 400 400 Floating rate notes due 2021 (0.892%) 2 400 400 Floating rate notes due 2022 (0.952%) 2 350 — 8.625% debentures due 2032 147 147 Amortizing Bank Loan due 2018 (1.172%) 2 110 — 8.625% debentures due 2031 108 107 8.0% debentures due 2032 74 74 9.75% debentures due 2020 54 54 8.875% debentures due 2021 40 40 Medium-term notes, maturing from 2021 to 2038 (5.975%) 1 38 38 Total including debt due within one year 27,071 15,960 Debt due within one year (1,487 ) — Reclassified from short-term debt 8,000 8,000 Total long-term debt $ 33,584 $ 23,960 1 Weighted-average interest rate at December 31, 2015 . 2 Interest rate at December 31, 2015.

Accounting for Suspended Expl53

Accounting for Suspended Exploratory Wells (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting for Suspended Exploratory Wells [Abstract]
Changes in company's suspended exploratory well costs	The following table indicates the changes to the company’s suspended exploratory well costs for the three years ended December 31, 2015 : 2015 2014 2013 Beginning balance at January 1 $ 4,195 $ 3,245 $ 2,681 Additions to capitalized exploratory well costs pending the determination of proved reserves 869 1,591 885 Reclassifications to wells, facilities and equipment based on the determination of proved reserves (164 ) (298 ) (290 ) Capitalized exploratory well costs charged to expense (1,397 ) (312 ) (31 ) Other reductions * (191 ) (31 ) — Ending balance at December 31 $ 3,312 $ 4,195 $ 3,245 * Represents property sales.
Aging of capitalized well costs and number of project	The following table provides an aging of capitalized well costs and the number of projects for which exploratory well costs have been capitalized for a period greater than one year since the completion of drilling. At December 31 2015 2014 2013 Exploratory well costs capitalized for a period of one year or less $ 489 $ 1,522 $ 641 Exploratory well costs capitalized for a period greater than one year 2,823 2,673 2,604 Balance at December 31 $ 3,312 $ 4,195 $ 3,245 Number of projects with exploratory well costs that have been capitalized for a period greater than one year * 39 51 51 * Certain projects have multiple wells or fields or both.
Aging of Costs on Well and Project Basis	The tables below contain the aging of these costs on a well and project basis: Aging based on drilling completion date of individual wells: Amount Number of wells 1998-2004 $ 285 26 2005-2009 395 33 2010-2014 2,143 106 Total $ 2,823 165 Aging based on drilling completion date of last suspended well in project: Amount Number of projects 2003-2007 $ 200 4 2008-2011 393 6 2012-2015 2,230 29 Total $ 2,823 39

Stock Options and Other Share54

Stock Options and Other Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Fair market values of stock options and stock appreciation rights granted	The fair market values of stock options and stock appreciation rights granted in 2015 , 2014 and 2013 were measured on the date of grant using the Black-Scholes option-pricing model, with the following weighted-average assumptions: Year ended December 31 2015 2014 2013 Expected term in years 1 6.1 6.0 6.0 Volatility 2 21.9 % 30.3 % 31.3 % Risk-free interest rate based on zero coupon U.S. treasury note 1.4 % 1.9 % 1.2 % Dividend yield 3.6 % 3.3 % 3.3 % Weighted-average fair value per option granted $ 13.89 $ 25.86 $ 24.48 1 Expected term is based on historical exercise and postvesting cancellation data. 2 Volatility rate is based on historical stock prices over an appropriate period, generally equal to the expected term.
Summary of option activity	A summary of option activity during 2015 is presented below: Shares (Thousands) Weighted-Average Exercise Price Averaged Remaining Contractual Term (Years) Aggregate Intrinsic Value Outstanding at January 1, 2015 78,341 $ 93.59 Granted 22,126 $ 103.71 Exercised (3,104 ) $ 62.06 Forfeited (3,071 ) $ 103.70 Outstanding at December 31, 2015 94,292 $ 96.67 5.83 $ 467 Exercisable at December 31, 2015 65,657 $ 91.85 4.61 $ 467

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2015
Compensation and Retirement Disclosure [Abstract]
Funded status of pension and other postretirement benefit plans	The funded status of the company’s pension and OPEB plans for 2015 and 2014 follows: Pension Benefits 2015 2014 Other Benefits U.S. Int’l. U.S. Int’l. 2015 2014 Change in Benefit Obligation Benefit obligation at January 1 $ 14,250 $ 5,767 $ 12,080 $ 6,095 $ 3,660 $ 3,138 Service cost 538 185 450 190 72 50 Interest cost 502 277 494 340 151 148 Plan participants' contributions — 6 — 8 148 150 Plan amendments — (6 ) — 3 — 2 Actuarial (gain) loss (345 ) (309 ) 2,299 336 (326 ) 544 Foreign currency exchange rate changes — (326 ) — (348 ) (37 ) (22 ) Benefits paid (1,382 ) (241 ) (1,073 ) (293 ) (344 ) (350 ) Divestitures — — — (564 ) — — Curtailment — (17 ) — — — — Benefit obligation at December 31 13,563 5,336 14,250 5,767 3,324 3,660 Change in Plan Assets Fair value of plan assets at January 1 11,090 4,244 11,210 4,543 — — Actual return on plan assets (75 ) 112 854 571 — — Foreign currency exchange rate changes — (239 ) — (279 ) — — Employer contributions 641 227 99 276 196 200 Plan participants' contributions — 6 — 8 148 150 Benefits paid (1,382 ) (241 ) (1,073 ) (293 ) (344 ) (350 ) Divestitures — — — (582 ) — — Fair value of plan assets at December 31 10,274 4,109 11,090 4,244 — — Funded Status at December 31 $ (3,289 ) $ (1,227 ) $ (3,160 ) $ (1,523 ) $ (3,324 ) $ (3,660 )
Consolidated Balance Sheet for pension and other postretirement benefit plans	Amounts recognized on the Consolidated Balance Sheet for the company’s pension and OPEB plans at December 31, 2015 and 2014 , include: Pension Benefits 2015 2014 Other Benefits U.S. Int’l. U.S. Int’l. 2015 2014 Deferred charges and other assets $ 13 $ 333 $ 13 $ 244 $ — $ — Accrued liabilities (153 ) (77 ) (123 ) (68 ) (191 ) (198 ) Noncurrent employee benefit plans (3,149 ) (1,483 ) (3,050 ) (1,699 ) (3,133 ) (3,462 ) Net amount recognized at December 31 $ (3,289 ) $ (1,227 ) $ (3,160 ) $ (1,523 ) $ (3,324 ) $ (3,660 )
Before tax basis amount in accumulated other comprehensive loss	Amounts recognized on a before-tax basis in “Accumulated other comprehensive loss” for the company’s pension and OPEB plans were $6,478 and $7,417 at the end of 2015 and 2014 , respectively. These amounts consisted of: Pension Benefits 2015 2014 Other Benefits U.S. Int’l. U.S. Int’l. 2015 2014 Net actuarial loss $ 4,809 $ 1,143 $ 4,972 $ 1,487 $ 367 $ 763 Prior service (credit) costs (5 ) 120 (13 ) 150 44 58 Total recognized at December 31 $ 4,804 $ 1,263 $ 4,959 $ 1,637 $ 411 $ 821
Pension plans with accumulated benefit obligation in excess of plan assets	Information for U.S. and international pension plans with an accumulated benefit obligation in excess of plan assets at December 31, 2015 and 2014 , was: Pension Benefits 2015 2014 U.S. Int’l. U.S. Int’l. Projected benefit obligations $ 13,500 $ 1,623 $ 14,182 $ 1,938 Accumulated benefit obligations 11,969 1,357 12,765 1,525 Fair value of plan assets 10,198 207 11,009 262
Components of net periodic benefit cost and amounts recognized in other comprehensive income	The components of net periodic benefit cost and amounts recognized in the Consolidated Statement of Comprehensive Income for 2015 , 2014 and 2013 are shown in the table below: Pension Benefits 2015 2014 2013 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2015 2014 2013 Net Periodic Benefit Cost Service cost $ 538 $ 185 $ 450 $ 190 $ 495 $ 197 $ 72 $ 50 $ 66 Interest cost 502 277 494 340 471 314 151 148 149 Expected return on plan assets (783 ) (262 ) (788 ) (298 ) (701 ) (274 ) — — — Amortization of prior service costs (credits) (8 ) 22 (9 ) 21 2 21 14 14 (50 ) Recognized actuarial losses 356 78 209 96 485 143 34 7 53 Settlement losses 320 6 237 208 173 12 — — — Curtailment losses (gains) — (14 ) — — — — — — — Total net periodic benefit cost 925 292 593 557 925 413 271 219 218 Changes Recognized in Comprehensive Income Net actuarial (gain) loss during period 513 (260 ) 2,233 (17 ) (2,244 ) (476 ) (362 ) 514 (659 ) Amortization of actuarial loss (676 ) (84 ) (446 ) (304 ) (658 ) (155 ) (34 ) (7 ) (53 ) Prior service (credits) costs during period — (6 ) — 4 (78 ) 18 — 2 — Amortization of prior service (costs) credits 8 (24 ) 9 (21 ) (2 ) (21 ) (14 ) (14 ) 50 Total changes recognized in other (155 ) (374 ) 1,796 (338 ) (2,982 ) (634 ) (410 ) 495 (662 ) Recognized in Net Periodic Benefit Cost and Other Comprehensive Income $ 770 $ (82 ) $ 2,389 $ 219 $ (2,057 ) $ (221 ) $ (139 ) $ 714 $ (444 )
Weighted-average assumptions used to determine benefit obligations and net periodic benefit costs	The following weighted-average assumptions were used to determine benefit obligations and net periodic benefit costs for years ended December 31: Pension Benefits 2015 2014 2013 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2015 2014 2013 Assumptions used to determine benefit obligations: Discount rate 4.0 % 5.3 % 3.7 % 5.0 % 4.3 % 5.8 % 4.6 % 4.3 % 4.9 % Rate of compensation increase 4.5 % 4.8 % 4.5 % 5.1 % 4.5 % 5.5 % N/A N/A N/A Assumptions used to determine net periodic benefit cost: Discount rate 3.7 % 5.0 % 4.3 % 5.8 % 3.6 % 5.2 % 4.3 % 4.9 % 4.1 % Expected return on plan assets 7.5 % 6.3 % 7.5 % 6.6 % 7.5 % 6.8 % N/A N/A N/A Rate of compensation increase 4.5 % 5.1 % 4.5 % 5.5 % 4.5 % 5.5 % N/A N/A N/A
Effects of change in the assumed health care cost-trend rates	A 1-percentage-point change in the assumed health care cost-trend rates would have the following effects on worldwide plans: 1 Percent Increase 1 Percent Decrease Effect on total service and interest cost components $ 20 $ (17 ) Effect on postretirement benefit obligation $ 192 $ (164 )
Fair value measurements of the Company's pension plans	U.S. Int’l. Total Fair Value Level 1 Level 2 Level 3 Total Fair Value Level 1 Level 2 Level 3 At December 31, 2014 Equities U.S. 1 $ 2,087 $ 2,087 $ — $ — $ 241 $ 241 $ — $ — International 1,297 1,297 — — 313 313 — — Collective Trusts/Mutual Funds 2 3,240 22 3,218 — 979 173 806 — Fixed Income Government 84 47 37 — 1,066 53 1,013 — Corporate 1,502 — 1,502 — 585 26 537 22 Mortgage-Backed Securities 1 — 1 — 1 — 1 — Other Asset Backed — — — — — — — — Collective Trusts/Mutual Funds 2 1,174 — 1,174 — 394 16 378 — Mixed Funds 3 — — — — 122 3 119 — Real Estate 4 1,364 — — 1,364 329 — — 329 Cash and Cash Equivalents 270 270 — — 190 189 1 — Other 5 71 (3 ) 20 54 24 — 21 3 Total at December 31, 2014 $ 11,090 $ 3,720 $ 5,952 $ 1,418 $ 4,244 $ 1,014 $ 2,876 $ 354 At December 31, 2015 Equities U.S. 1 $ 1,699 $ 1,699 $ — $ — $ 392 $ 382 $ 10 $ — International 1,302 1,296 6 — 457 435 22 — Collective Trusts/Mutual Funds 2 2,460 18 2,442 — 572 7 565 — Fixed Income Government 257 46 211 — 1,089 93 996 — Corporate 1,654 — 1,654 — 615 33 557 25 Bank Loans 148 — 148 — — — — — Mortgage-Backed Securities 1 — 1 — 1 — 1 — Other Asset Backed 1 — 1 — — — — — Collective Trusts/Mutual Funds 2 933 — 933 — 269 12 257 — Mixed Funds 3 — — — — 85 4 81 — Real Estate 4 1,494 — — 1,494 378 — — 378 Cash and Cash Equivalents 253 253 — — 232 232 — — Other 5 72 (6 ) 26 52 19 (2 ) 19 2 Total at December 31, 2015 $ 10,274 $ 3,306 $ 5,422 $ 1,546 $ 4,109 $ 1,196 $ 2,508 $ 405 1 U.S. equities include investments in the company’s common stock in the amount of $9 at December 31, 2015 , and $24 at December 31, 2014 . 2 Collective Trusts/Mutual Funds for U.S. plans are entirely index funds; for International plans, they are mostly index funds. For these index funds, the Level 2 designation is partially based on the restriction that advance notification of redemptions, typically two business days, is required. 3 Mixed funds are composed of funds that invest in both equity and fixed-income instruments in order to diversify and lower risk. 4 The year-end valuations of the U.S. real estate assets are based on internal appraisals by the real estate managers, which are updates of third-party appraisals that occur at least once a year for each property in the portfolio. 5 The “Other” asset class includes net payables for securities purchased but not yet settled (Level 1); dividends and interest- and tax-related receivables (Level 2); insurance contracts and investments in private-equity limited partnerships (Level 3).
The effect of fair-value measurements using significant unobservable inputs on changes in Level 3 plan assets for the period	The effects of fair value measurements using significant unobservable inputs on changes in Level 3 plan assets are outlined below: Fixed Income Corporate Mortgage-Backed Securities Real Estate Other Total Total at December 31, 2013 $ 23 $ 2 $ 1,559 $ 57 $ 1,641 Actual Return on Plan Assets: Assets held at the reporting date — — 115 — 115 Assets sold during the period — — 20 — 20 Purchases, Sales and Settlements (1 ) (2 ) (1 ) — (4 ) Transfers in and/or out of Level 3 — — — — — Total at December 31, 2014 $ 22 $ — $ 1,693 $ 57 $ 1,772 Actual Return on Plan Assets: Assets held at the reporting date (3 ) — 149 (1 ) 145 Assets sold during the period — — 23 — 23 Purchases, Sales and Settlements 6 — 7 (2 ) 11 Transfers in and/or out of Level 3 — — — — — Total at December 31, 2015 $ 25 $ — $ 1,872 $ 54 $ 1,951
Benefit payments, which include estimated future service that are expected to be paid by the company in the next 10 years	The following benefit payments, which include estimated future service, are expected to be paid by the company in the next 10 years: Pension Benefits Other U.S. Int’l. Benefits 2016 $ 1,462 $ 284 $ 191 2017 $ 1,384 $ 297 $ 195 2018 $ 1,360 $ 467 $ 199 2019 $ 1,329 $ 339 $ 203 2020 $ 1,287 $ 346 $ 207 2021-2025 $ 5,804 $ 1,822 $ 1,053

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Changes to the Company's Before-tax Asset Retirement Obligation	The following table indicates the changes to the company’s before-tax asset retirement obligations in 2015 , 2014 and 2013 : 2015 2014 2013 Balance at January 1 $ 15,053 $ 14,298 $ 13,271 Liabilities incurred 51 133 59 Liabilities settled (981 ) (1,291 ) (907 ) Accretion expense 715 882 627 Revisions in estimated cash flows 804 1,031 1,248 Balance at December 31 $ 15,642 $ 15,053 $ 14,298

Restructuring and Reorganizat57

Restructuring and Reorganization Costs (Tables)	12 Months Ended
	Dec. 31, 2015
Restructuring and Related Activities [Abstract]
Schedule of Restructuring and Related Costs	The following table summarizes the accrued severance liability, which is classified as current on the Consolidated Balance Sheet: Amounts Before Tax Balance at January 1, 2015 $ — Accruals/Adjustments 353 Payments (60 ) Balance at December 31, 2015 $ 293

Other Financial Information (Ta

Other Financial Information (Tables)	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Other Financial Information	Other financial information is as follows: Year ended December 31 2015 2014 2013 Total financing interest and debt costs $ 495 $ 358 $ 284 Less: Capitalized interest 495 358 284 Interest and debt expense $ — $ — $ — Research and development expenses $ 601 $ 707 $ 750 Excess of replacement cost over the carrying value of inventories (LIFO method) 3,745 8,135 9,150 LIFO (losses) / profits on inventory drawdowns included in earnings (65 ) 13 14 Foreign currency effects* $ 769 $ 487 $ 474 * Includes $344 , $118 and $244 in 2015 , 2014 and 2013 , respectively, for the company’s share of equity affiliates’ foreign currency effects.

Summary of Significant Accoun59

Summary of Significant Accounting Policies (Details Textual)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Maturity period of bank time deposits reported as time deposits, minimum	90 days

Changes in Accumulated Other 60

Changes in Accumulated Other Comprehensive Losses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at January 1	$ (4,859)
Components of Other Comprehensive Income (Loss):
Before Reclassifications	61
Reclassifications	507
Other Comprehensive Gain (Loss), Net of Tax	568	$ (1,280)	$ 2,790
Balance at December 31	(4,291)	(4,859)
Income tax expense	132	11,892	14,308
Currency Translation Adjustment [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at January 1	(96)
Components of Other Comprehensive Income (Loss):
Before Reclassifications	(44)
Reclassifications	0
Other Comprehensive Gain (Loss), Net of Tax	(44)	(73)	42
Balance at December 31	(140)	(96)
Unrealized Holding Gains (Losses) on Securities [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at January 1	(8)
Components of Other Comprehensive Income (Loss):
Before Reclassifications	(21)
Reclassifications	0
Other Comprehensive Gain (Loss), Net of Tax	(21)	(2)	(7)
Balance at December 31	(29)	(8)
Derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at January 1	(2)
Components of Other Comprehensive Income (Loss):
Before Reclassifications	0
Reclassifications	0
Other Comprehensive Gain (Loss), Net of Tax	0	(54)	(73)
Balance at December 31	(2)	(2)
Defined Benefit Plans [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at January 1	(4,753)
Components of Other Comprehensive Income (Loss):
Before Reclassifications	126
Reclassifications	507
Other Comprehensive Gain (Loss), Net of Tax	633	(1,151)	$ 2,828
Balance at December 31	(4,120)	$ (4,753)
Defined Benefit Plans [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Components of Other Comprehensive Income (Loss):
Employee benefits reclassification component, included in employee benefit costs	824
Income tax expense	$ 317

Noncontrolling Interests (Detai

Noncontrolling Interests (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Activity for equity attributable to noncontrolling interests
Balance at January 1	$ 156,191	$ 150,427
Net Income	4,710	19,310	$ 21,597
Balance at December 31	153,886	156,191	150,427
Noncontrolling Interests
Activity for equity attributable to noncontrolling interests
Balance at January 1	1,163	1,314	1,308
Net Income	123	69	174
Distributions to noncontrolling interests	(128)	(47)	(99)
Other changes, net	12	(173)	(69)
Balance at December 31	$ 1,170	$ 1,163	$ 1,314

Information Relating to the C62

Information Relating to the Consolidated Statement of Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Net increase in operating working capital was composed of the following:
Decrease (increase) in accounts and notes receivable	$ 3,631	$ 4,491	$ (1,101)
Decrease (increase) in inventories	85	(146)	(237)
Decrease (increase) in prepaid expenses and other current assets	713	(407)	834
(Decrease) increase in accounts payable and accrued liabilities	(5,769)	(3,737)	160
Decrease in income and other taxes payable	(639)	(741)	(987)
Net increase in operating working capital	(1,979)	(540)	(1,331)
Net cash provided by operating activities includes the following cash payments for income taxes:
Income taxes	4,645	10,562	12,898
Net sales (purchases) of marketable securities consisted of the following gross amounts:
Marketable securities purchased	(6)	(162)	(7)
Marketable securities sold	128	14	10
Net sales (purchases) of marketable securities	122	(148)	3
Net maturities of time deposits consisted of the following gross amounts:
Time deposits purchased	0	(317)	(2,317)
Time deposits matured	8	317	3,017
Net sales (purchases) of time deposits	8	0	700
Net (repayments) borrowings of short-term obligations consisted of the following gross and net amounts:
Proceeds from issuances of short-term obligations	13,805	9,070	1,551
Repayments of short-term obligations	(16,379)	(4,612)	(375)
Net borrowings (repayments) of short-term obligations with three months or less maturity	2,239	(1,027)	1,202
Net (repayments) borrowings of short-term obligations	(335)	3,431	2,378
Capital expenditures
Additions to properties, plant and equipment	28,213	34,393	36,550	[1]
Additions to investments	555	526	934
Current-year dry hole expenditures	736	504	594
Payments for other liabilities and assets, net	0	(16)	(93)
Capital expenditures	29,504	35,407	37,985
Expensed exploration expenditures	1,031	1,110	1,178
Assets acquired through capital lease obligations and other financing obligations	47	332	16
Capital and exploratory expenditures, excluding equity affiliates	30,582	36,849	39,179
Company's share of expenditures by equity affiliates	3,397	3,467	2,698
Capital and exploratory expenditures, including equity affiliates	$ 33,979	$ 40,316	$ 41,877
[1]	Excludes noncash additions of $1,362 in 2015, $2,310 in 2014 and $1,661 in 2013.

Information Relating to the C63

Information Relating to the Consolidated Statement of Cash Flows (Details 1) - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Additional Information Relating to the Consolidated Statement of Cash Flows (Textual) [Abstract]
Reduction for income tax benefits associated with stock options exercised	$ 17	$ 58	$ 79
Share repurchase price	2	$ 5,006	$ 5,004
Stock repurchased during period, shares		41.5	41.6
Stock repurchased during period, value		$ 5,000	$ 5,000
Non-cash reduction to property, plant and equipment	3,700
Noncash additions to properties, plant and equipment	$ 1,362	$ 2,310	$ 1,661

Lease Commitments (Details)

Lease Commitments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating Leased Assets [Line Items]
Non-cancelable term of operating and capital leases (in years)	1 year
Schedule of capitalized leased assets
Upstream	$ 800	$ 765
Downstream	98	97
All Other	0	0
Total	898	862
Less: Accumulated amortization	448	381
Net capitalized leased assets	450	481
Rental expenses incurred for operating leases
Minimum rentals	1,041	1,080	$ 1,049
Contingent rentals	2	1	1
Total	1,043	1,081	1,050
Less: Sublease rental income	9	14	25
Net rental expense	1,034	1,067	$ 1,025
Estimated future minimum lease payments (net of noncancelable sublease rentals) under operating and capital leases
Operating Leases, 2016	846
Capital Leases, 2016	23
Operating Leases, 2017	689
Capital Leases, 2017	21
Operating Leases, 2018	554
Capital Leases, 2018	19
Operating Leases, 2019	420
Capital Leases, 2019	19
Operating Leases, 2020	311
Capital Leases, 2020	6
Operating Leases, Thereafter	528
Capital Leases, Thereafter	62
Operating Leases, Total	3,348
Capital Leases, Total	150
Less: Amounts representing interest and executory costs	(53)
Net present values	97
Less: Capital lease obligations included in short-term debt	(17)
Long-term capital lease obligations	$ 80	$ 68
Maximum [Member]
Operating Leased Assets [Line Items]
Contingent rentals, renewal option term (in years)	25 years

Summarized Financial Data - C65

Summarized Financial Data - Chevron U.S.A. Inc. (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Subsidiary Statements Captions [Line Items]
Sales and other operating revenues	[1]	$ 129,925	$ 200,494	$ 220,156
Total costs and other deductions		133,635	180,768	192,943
Net income (loss) attributable to CUSA	[2]	4,587	19,241	21,423
Chevron U.S.A. Inc. [Member]
Subsidiary Statements Captions [Line Items]
Sales and other operating revenues		97,766	157,198	174,318
Total costs and other deductions		101,565	153,139	169,984
Net income (loss) attributable to CUSA		$ (1,054)	$ 3,849	$ 3,714
[1]	Includes excise, value-added and similar taxes. $7,359; $8,186; $8,492.
[2]	There was no effect of dividend equivalents paid on stock units or dilutive impact of employee stock-based awards on earnings.

Summarized Financial Data - C66

Summarized Financial Data - Chevron U.S.A. Inc. (Details 1) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Subsidiary Statements Captions [Line Items]
Current assets	$ 35,347	$ 42,232
Current liabilities	26,464	31,926
Total CUSA net equity	153,886	156,191	$ 150,427
Chevron U.S.A. Inc. [Member]
Subsidiary Statements Captions [Line Items]
Current assets	9,732	13,724
Other assets	59,170	62,195
Current liabilities	13,664	16,191
Other liabilities	29,100	30,175
Total CUSA net equity	26,138	29,553
Memo: Total debt	$ 14,462	$ 14,473

Summarized Financial Data - T67

Summarized Financial Data - Tengizchevroil LLP (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Affiliate Statements Captions [Line Items]
Percentage of affiliate by summarized financial information	100.00%
Tengizchevroil LLP [Member]
Affiliate Statements Captions [Line Items]
Sales and other operating revenues	$ 12,811	$ 22,813	$ 25,239
Costs and other deductions	7,257	10,275	11,173
Net income attributable to TCO	$ 3,897	$ 8,772	$ 9,855
Tengizchevroil LLP [Member]
Affiliate Statements Captions [Line Items]
Equity method investment, ownership percentage	50.00%
Percentage of affiliate by summarized financial information	100.00%

Summarized Financial Data - T68

Summarized Financial Data - Tengizchevroil LLP (Details 1) - Tengizchevroil LLP [Member] - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Affiliate Statements Captions [Line Items]
Current assets	$ 2,098	$ 3,425
Other assets	17,094	14,810
Current liabilities	1,063	1,531
Other liabilities	2,266	2,375
Total TCO net equity	$ 15,863	$ 14,329

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives	$ 205	$ 413
Derivatives	53	84
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	310	422
Derivatives	205	413
Total Assets at Fair Value	515	835
Derivatives	53	84
Total Liabilities at Fair Value	53	84
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	310	422
Derivatives	189	394
Total Assets at Fair Value	499	816
Derivatives	47	83
Total Liabilities at Fair Value	47	83
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	0	0
Derivatives	16	19
Total Assets at Fair Value	16	19
Derivatives	6	1
Total Liabilities at Fair Value	6	1
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	0	0
Derivatives	0	0
Total Assets at Fair Value	0	0
Derivatives	0	0
Total Liabilities at Fair Value	$ 0	$ 0

Fair Value Measurements (Deta70

Fair Value Measurements (Details 1) - Fair Value, Measurements, Nonrecurring [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Properties, plant and equipment, net (held and used)	$ 3,051	$ 947
Properties, plant and equipment, net (held for sale)	937	0
Investments and advances	75	11
Total Nonrecurring Assets at Fair Value	4,063	958
Properties, plant and equipment, net (held and used), Before-Tax Loss	3,222	1,249
Properties, plant and equipment, net (held for sale), Before-Tax Loss	844	25
Investments and advances, Before-Tax Loss	28	41
Total Nonrecurring Assets at Fair Value, Before-Tax Loss	4,094	1,315
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Properties, plant and equipment, net (held and used)	0	0
Properties, plant and equipment, net (held for sale)	0	0
Investments and advances	0	0
Total Nonrecurring Assets at Fair Value	0	0
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Properties, plant and equipment, net (held and used)	239	213
Properties, plant and equipment, net (held for sale)	937	0
Investments and advances	75	0
Total Nonrecurring Assets at Fair Value	1,251	213
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Properties, plant and equipment, net (held and used)	2,812	734
Properties, plant and equipment, net (held for sale)	0	0
Investments and advances	0	11
Total Nonrecurring Assets at Fair Value	$ 2,812	$ 745

Fair Value Measurements (Deta71

Fair Value Measurements (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying/fair value of cash and cash equivalents	$ 11,022	$ 12,785	$ 16,245	$ 20,939
Maturity period of bank time deposits reported as time deposits, minimum	90 days
Carrying/fair value of time deposits	$ 0	8
Carrying/fair value of investments not included in cash and cash equivalents	1,100	1,474
Carrying amount of long-term debt	27,071	15,960
Corporate Bond Securities [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of debt	25,117
Other Bond Securities [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of debt	767
Carrying Amount of Long-term Debt [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying amount of long-term debt	25,584	15,960
Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying amount of long-term debt	$ 25,884	$ 16,450
Maximum [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Maturity period of primarily bank time deposits, classified as cash equivalents, maximum	90 days

Financial and Derivative Inst72

Financial and Derivative Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Total Assets at Fair Value	$ 205	$ 413
Total Liabilities at Fair Value	53	84
Commodity Contract [Member] | Accounts and notes receivable, net [Member]
Derivatives, Fair Value [Line Items]
Total Assets at Fair Value	200	401
Commodity Contract [Member] | Long term receivables, net [Member]
Derivatives, Fair Value [Line Items]
Total Assets at Fair Value	5	12
Commodity Contract [Member] | Accounts payable [Member]
Derivatives, Fair Value [Line Items]
Total Liabilities at Fair Value	51	57
Commodity Contract [Member] | Deferred credits and other noncurrent obligations [Member]
Derivatives, Fair Value [Line Items]
Total Liabilities at Fair Value	$ 2	$ 27

Financial and Derivative Inst73

Financial and Derivative Instruments Financial and Derivative Instruments (Details 1) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ 304	$ 504	$ (194)
Commodity Contract [Member] | Sales and other operating revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	277	553	(108)
Commodity Contract [Member] | Purchased crude oil and products [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	30	(17)	(77)
Commodity Contract [Member] | Other Income [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ (3)	$ (32)	$ (9)

Financial and Derivative Inst74

Financial and Derivative Instruments Financial and Derivative Instruments (Details 2) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Offsetting Assets [Abstract]
Derivative Asset, Gross Amount Recognized	$ 2,459	$ 4,004
Derivative Asset, Gross Amounts Offset	2,254	3,591
Derivative Asset, Net Amounts Presented	205	413
Derivative Assets, Gross Amounts Not Offset	0	7
Derivative Asset, Net Amount	205	406
Offsetting Liabilities [Abstract]
Derivative Liability, Gross Amount Recognized	2,307	3,675
Derivative Liability, Gross Amounts Offset	2,254	3,591
Derivative Liability, Net Amounts Presented	53	84
Derivative Liabilities, Gross Amounts Not Offset	0	0
Derivative Liability, Net Amount	$ 53	$ 84

Assets Held For Sale (Details)

Assets Held For Sale (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Assets Held For Sale [Abstract]
Assets held for sale	$ 1,449	$ 0

Equity (Details)

Equity (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Company's share of undistributed earnings for equity affiliates	$ 15,010	$ 14,512
Shares remaining available for issuance	120,753
Shares available for issuance	800,000
Chevron Long-Term Incentive Plan (LTIP) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares remaining available for issuance	114,000,000
Shares available for issuance	260,000,000

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
Basic EPS Calculation
Earnings available to common stockholders - Basic	[1]	$ 4,587	$ 19,241	$ 21,423
Weighted-average number of common shares outstanding		1,867	1,883	1,916
Add: Deferred awards held as stock units		1	1	1
Total weighted-average number of common shares outstanding		1,868	1,884	1,917
Earnings per share of common stock - Basic		$ 2.46	$ 10.21	$ 11.18
Diluted EPS Calculation
Earnings available to common stockholders - Diluted	[1]	$ 4,587	$ 19,241	$ 21,423
Weighted-average number of common shares outstanding		1,867	1,883	1,916
Add: Deferred awards held as stock units		1	1	1
Add: Dilutive effect of employee stock-based awards		7	14	15
Total weighted-average number of common shares outstanding		1,875	1,898	1,932
Earnings per share of common stock - Diluted		$ 2.45	$ 10.14	$ 11.09
[1]	There was no effect of dividend equivalents paid on stock units or dilutive impact of employee stock-based awards on earnings.

Operating Segments and Geogra78

Operating Segments and Geographic Data (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Net income attributable to Chevron Corporation	[1]	$ 4,587	$ 19,241	$ 21,423
Operating Segments [Member]
Segment Reporting Information [Line Items]
Net income attributable to Chevron Corporation		5,640	21,229	23,046
Operating Segments [Member] | Upstream [Member]
Segment Reporting Information [Line Items]
Net income attributable to Chevron Corporation		(1,961)	16,893	20,809
Operating Segments [Member] | Upstream [Member] | United States [Member]
Segment Reporting Information [Line Items]
Net income attributable to Chevron Corporation		(4,055)	3,327	4,044
Operating Segments [Member] | Upstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Net income attributable to Chevron Corporation		2,094	13,566	16,765
Operating Segments [Member] | Downstream [Member]
Segment Reporting Information [Line Items]
Net income attributable to Chevron Corporation		7,601	4,336	2,237
Operating Segments [Member] | Downstream [Member] | United States [Member]
Segment Reporting Information [Line Items]
Net income attributable to Chevron Corporation		3,182	2,637	787
Operating Segments [Member] | Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Net income attributable to Chevron Corporation		4,419	1,699	1,450
Segment Reconciling Items [Member]
Segment Reporting Information [Line Items]
Interest income		65	77	80
Other		$ (1,118)	$ (2,065)	$ (1,703)
[1]	There was no effect of dividend equivalents paid on stock units or dilutive impact of employee stock-based awards on earnings.

Operating Segments and Geogra79

Operating Segments and Geographic Data (Details 1) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	[1]
Segment Assets
Goodwill	$ 4,588	$ 4,593
Total Assets	266,103	266,026
United States [Member]
Segment Assets
Total Assets	72,891	79,014
International [Member]
Segment Assets
Total Assets	188,624	182,419
Operating Segments [Member]
Segment Assets
Total Assets	250,602	247,463
Operating Segments [Member] | Upstream [Member]
Segment Assets
Goodwill	4,588	4,593
Total Assets	214,212	206,672
Operating Segments [Member] | Upstream [Member] | United States [Member]
Segment Assets
Total Assets	46,407	49,343
Operating Segments [Member] | Upstream [Member] | International [Member]
Segment Assets
Total Assets	163,217	152,736
Operating Segments [Member] | Downstream [Member]
Segment Assets
Total Assets	36,390	40,791
Operating Segments [Member] | Downstream [Member] | United States [Member]
Segment Assets
Total Assets	21,408	23,068
Operating Segments [Member] | Downstream [Member] | International [Member]
Segment Assets
Total Assets	14,982	17,723
Corporate, Non-Segment [Member]
Segment Assets
Total Assets	15,501	18,563
Corporate, Non-Segment [Member] | United States [Member]
Segment Assets
Total Assets	5,076	6,603
Corporate, Non-Segment [Member] | International [Member]
Segment Assets
Total Assets	$ 10,425	$ 11,960
[1]	2014 conformed to 2015 presentation

Operating Segments and Geogra80

Operating Segments and Geographic Data (Details 2) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Sales and other operating revenues	[1]	$ 129,925	$ 200,494	$ 220,156
Upstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		4,117	7,455	8,052
Upstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		15,587	23,808	17,607
Downstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		48,420	73,942	80,272
Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		54,296	86,848	105,373
All Other [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		141	252	358
All Other [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		5	3	3
Intersegment Eliminations [Member] | Upstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		8,631	15,455	16,865
Intersegment Eliminations [Member] | Upstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		11,492	23,107	33,034
Intersegment Eliminations [Member] | Downstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		26	31	39
Intersegment Eliminations [Member] | Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		1,528	8,839	859
Operating Segments [Member] | Upstream [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	[2]	39,827	69,825	75,558
Operating Segments [Member] | Upstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		12,748	22,910	24,917
Operating Segments [Member] | Upstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		27,079	46,915	50,641
Operating Segments [Member] | Downstream [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	[2]	111,629	177,846	195,034
Operating Segments [Member] | Downstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		52,872	78,606	85,103
Operating Segments [Member] | Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		58,757	99,240	109,931
Other Segment Reconciling Item: Excise and Similar Taxes [Member] | Downstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		4,426	4,633	4,792
Other Segment Reconciling Item: Excise and Similar Taxes [Member] | Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		2,933	3,553	3,699
Intersegment Eliminations, Corporate, Non-Segment [Member] | All Other [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		1,372	1,475	1,524
Intersegment Eliminations, Corporate, Non-Segment [Member] | All Other [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		37	28	31
Corporate, Non-Segment [Member] | All Other [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		1,555	1,758	1,916
Corporate, Non-Segment [Member] | All Other [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		1,513	1,727	1,882
Corporate, Non-Segment [Member] | All Other [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		42	31	34
Operating Segments and Coporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		153,011	249,429	272,508
Operating Segments and Coporate, Non-Segment [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		67,133	103,243	111,902
Operating Segments and Coporate, Non-Segment [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		85,878	146,186	160,606
Intersegment Eliminations, Operating Segments and Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		$ (23,086)	$ (48,935)	$ (52,352)
[1]	Includes excise, value-added and similar taxes. $7,359; $8,186; $8,492.
[2]	Effective January 1, 2014, International Upstream prospectively includes selected amounts previously recognized in International Downstream, which are not material to the segments.

Operating Segments and Geogra81

Operating Segments and Geographic Data (Details 3) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Total Income Tax Expense	$ 132	$ 11,892	$ 14,308
Operating Segments [Member] | Upstream [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense	(827)	11,260	14,803
Operating Segments [Member] | Upstream [Member] | United States [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense	(2,041)	2,043	2,333
Operating Segments [Member] | Upstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense	1,214	9,217	12,470
Operating Segments [Member] | Downstream [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense	2,633	1,769	753
Operating Segments [Member] | Downstream [Member] | United States [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense	1,320	1,302	364
Operating Segments [Member] | Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense	1,313	467	389
Corporate, Non-Segment [Member] | All Other [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense	$ (1,674)	$ (1,137)	$ (1,248)

Operating Segments and Geogra82

Operating Segments and Geographic Data (Details Textual) - segment	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting [Abstract]
Number of reportable segments	2
Number of operating segments		2

Investments and Advances (Detai

Investments and Advances (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	$ 26,578	$ 26,335
Other at or below cost	[1]	532	577
Total investments and advances	[1]	27,110	26,912
Equity in Earnings		4,684	7,098	$ 7,527
Investments and Advances [Member] | United States [Member]
Schedule of Equity Method Investments [Line Items]
Total investments and advances	[1]	6,863	6,787
Investments and Advances [Member] | International [Member]
Schedule of Equity Method Investments [Line Items]
Total investments and advances	[1]	20,247	20,125
Equity in Earnings [Member] | United States [Member]
Schedule of Equity Method Investments [Line Items]
Equity in Earnings		1,342	1,623	1,294
Equity in Earnings [Member] | International [Member]
Schedule of Equity Method Investments [Line Items]
Equity in Earnings		3,342	5,475	6,233
Upstream [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	16,703	16,110
Equity in Earnings		2,218	4,713	5,812
Upstream [Member] | Tengizchevroil LLP [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	8,077	7,319
Equity in Earnings		1,939	4,392	4,957
Upstream [Member] | Petropiar [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	679	794
Equity in Earnings		180	26	339
Upstream [Member] | Caspian Pipeline Consortium [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	1,342	1,487
Equity in Earnings		162	191	113
Upstream [Member] | Petroboscan [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	1,163	917
Equity in Earnings		219	186	300
Upstream [Member] | Angola LNG Limited [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	3,284	3,277
Equity in Earnings		(417)	(311)	(111)
Upstream [Member] | Other [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	2,158	2,316
Equity in Earnings		135	229	214
Downstream [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	9,893	10,192
Equity in Earnings		2,469	2,389	1,926
Downstream [Member] | Other [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	1,077	1,048
Equity in Earnings		186	180	199
Downstream [Member] | GS Caltex Corporation [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	3,620	2,867
Equity in Earnings		824	420	132
Downstream [Member] | Chevron Phillips Chemical Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	5,196	5,116
Equity in Earnings		1,367	1,606	1,371
Downstream [Member] | Caltex Australia Limited [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	0	1,161
Equity in Earnings		92	183	224
All Other [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	[1]	(18)	33
Equity in Earnings		$ (3)	$ (4)	$ (211)
[1]	2014 conformed to 2015 presentation

Investments and Advances (Det84

Investments and Advances (Details 1) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Affiliates [Member]
Schedule of Investments [Line Items]
Total revenues	$ 71,389	$ 123,003	$ 131,875
Income before income tax expense	13,129	20,609	24,075
Net income attributable to affiliates	10,649	14,758	15,594
Current assets	27,162	35,662	39,713
Noncurrent assets	71,650	70,817	68,593
Current liabilities	20,559	25,308	29,642
Noncurrent liabilities	18,560	17,983	19,442
Total affiliates' net equity	59,693	63,188	59,222
Parent [Member]
Schedule of Investments [Line Items]
Total revenues	33,492	58,937	63,101
Income before income tax expense	6,279	9,968	11,108
Net income attributable to affiliates	4,691	7,237	7,845
Current assets	10,657	13,465	15,156
Noncurrent assets	26,607	26,053	25,059
Current liabilities	7,351	9,588	11,587
Noncurrent liabilities	3,909	4,211	4,559
Total affiliates' net equity	$ 26,004	$ 25,719	$ 24,069

Investments and Advances (Det85

Investments and Advances (Details 2) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Variable Interest Entity [Line Items]
Percentage of affiliate by summarized financial information		100.00%
Investments and advances	[1]	$ 26,578	$ 26,335
Related Party Transaction, Other Revenues from Transactions with Related Party		4,850	10,404	$ 14,635
Purchased crude oil and products		69,751	119,671	134,696
Accounts and notes receivable due from affiliated companies		399	924
Accounts payable due to affiliated companies		286	345
Chevron's loan to affiliates		410	874	1,129
Affiliated Entity [Member]
Variable Interest Entity [Line Items]
Purchased crude oil and products		$ 4,240	$ 6,735	$ 7,063
Tengizchevroil LLP [Member]
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage		50.00%
Chevron investment carrying value over underlying equity in TCO's net assets		$ 150
Petropiar [Member]
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage		30.00%
Chevron investment carrying value less underlying equity in Petropiar net assets		$ 160
Caspian Pipeline Consortium [Member]
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage		15.00%
Long term loans of Caspian Pipeline Consortium included in investments and advances		$ 1,098
Percentage of Caspian Pipeline Consortium pipeline construction funded by Loans		30.00%
Petroboscan [Member]
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage		39.20%
Chevron investment carrying value over underlying equity in Petroboscan's net assets		$ 140
Angola LNG Limited [Member]
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage		36.40%
GS Caltex Corporation [Member]
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage		50.00%
Chevron Phillips Chemical Company LLC [Member]
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage		50.00%
Caltex Australia Limited [Member]
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage sold		50.00%
Tengizchevroil LLP [Member]
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage		50.00%
Percentage of affiliate by summarized financial information		100.00%
[1]	2014 conformed to 2015 presentation

Properties, Plant and Equipme86

Properties, Plant and Equipment (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Properties, Plant and Equipment
Gross Investment at Cost	[1]	$ 340,277	$ 327,289	$ 296,433
Net Investment	[1]	188,396	183,173	164,829
Additions at Cost	[1],[2]	28,002	36,332	38,122
Depreciation Expense	[1],[3]	21,037	16,793	14,186
United States [Member]
Properties, Plant and Equipment
Gross Investment at Cost	[1]	122,550	125,163	117,364
Net Investment	[1]	56,791	59,960	56,506
Additions at Cost	[1],[2]	7,639	10,857	10,063
Depreciation Expense	[1],[3]	9,862	6,693	5,478
International [Member]
Properties, Plant and Equipment
Gross Investment at Cost	[1]	217,727	202,126	179,069
Net Investment	[1]	131,605	123,213	108,323
Additions at Cost	[1],[2]	20,363	25,475	28,059
Depreciation Expense	[1],[3]	11,175	10,100	8,708
Upstream [Member]
Properties, Plant and Equipment
Gross Investment at Cost	[1]	302,243	289,487	259,178
Net Investment	[1]	170,584	164,790	145,931
Additions at Cost	[1],[2]	26,579	34,608	35,571
Depreciation Expense	[1],[3]	19,348	14,815	12,748
Upstream [Member] | United States [Member]
Properties, Plant and Equipment
Gross Investment at Cost	[1]	93,848	96,850	89,555
Net Investment	[1]	43,125	45,864	41,831
Additions at Cost	[1],[2]	6,586	9,688	8,188
Depreciation Expense	[1],[3]	8,545	5,127	4,412
Upstream [Member] | International [Member]
Properties, Plant and Equipment
Gross Investment at Cost	[1]	208,395	192,637	169,623
Net Investment	[1]	127,459	118,926	104,100
Additions at Cost	[1],[2]	19,993	24,920	27,383
Depreciation Expense	[1],[3]	10,803	9,688	8,336
Downstream [Member]
Properties, Plant and Equipment
Gross Investment at Cost	[1]	32,379	31,974	31,710
Net Investment	[1]	14,897	15,238	15,620
Additions at Cost	[1],[2]	1,061	1,118	1,807
Depreciation Expense	[1],[3]	1,233	1,282	1,140
Downstream [Member] | United States [Member]
Properties, Plant and Equipment
Gross Investment at Cost	[1]	23,202	22,640	22,407
Net Investment	[1]	10,807	11,019	11,481
Additions at Cost	[1],[2]	696	588	1,154
Depreciation Expense	[1],[3]	878	886	780
Downstream [Member] | International [Member]
Properties, Plant and Equipment
Gross Investment at Cost	[1]	9,177	9,334	9,303
Net Investment	[1]	4,090	4,219	4,139
Additions at Cost	[1],[2]	365	530	653
Depreciation Expense	[1],[3]	355	396	360
All Other Segments [Member]
Properties, Plant and Equipment
Gross Investment at Cost	[1]	5,655	5,828	5,545
Net Investment	[1]	2,915	3,145	3,278
Additions at Cost	[1],[2]	362	606	744
Depreciation Expense	[1],[3]	456	696	298
All Other Segments [Member] | United States [Member]
Properties, Plant and Equipment
Gross Investment at Cost	[1]	5,500	5,673	5,402
Net Investment	[1]	2,859	3,077	3,194
Additions at Cost	[1],[2]	357	581	721
Depreciation Expense	[1],[3]	439	680	286
All Other Segments [Member] | International [Member]
Properties, Plant and Equipment
Gross Investment at Cost	[1]	155	155	143
Net Investment	[1]	56	68	84
Additions at Cost	[1],[2]	5	25	23
Depreciation Expense	[1],[3]	$ 17	$ 16	$ 12
[1]	Other than the United States, Australia and Nigeria, no other country accounted for 10 percent or more of the company’s net properties, plant and equipment (PP&E) in 2015. Australia had $49,205, $41,012 and $31,464 in 2015, 2014, and 2013, respectively. Nigeria had PP&E of $18,773, $19,214 and $18,429 for 2015, 2014 and 2013, respectively.
[2]	Net of dry hole expense related to prior years’ expenditures of $1,573, $371 and $89 in 2015, 2014 and 2013, respectively.
[3]	Depreciation expense includes accretion expense of $715, $882 and $627 in 2015, 2014 and 2013, respectively

Properties, Plant and Equipme87

Properties, Plant and Equipment (Details Textual) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, plant and equipment	[1]	$ 188,396	$ 183,173	$ 164,829
Dry hole expense related to prior years expenditures, net		1,573	371	89
Accretion expense		715	882	627
Impairment charges		4,066	1,274	382
Australia [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment		49,205	41,012	31,464
Nigeria [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment		$ 18,773	$ 19,214	$ 18,429
[1]	Other than the United States, Australia and Nigeria, no other country accounted for 10 percent or more of the company’s net properties, plant and equipment (PP&E) in 2015. Australia had $49,205, $41,012 and $31,464 in 2015, 2014, and 2013, respectively. Nigeria had PP&E of $18,773, $19,214 and $18,429 for 2015, 2014 and 2013, respectively.

Litigation (Details)

Litigation (Details) $ in Millions	Aug. 03, 2012USD ($)	Feb. 14, 2011USD ($)	Sep. 30, 2010USD ($)	Aug. 31, 2010	Dec. 31, 2015LegalMatterbreach	Dec. 31, 1998USD ($)	Nov. 13, 2013USD ($)	Jul. 02, 2013USD ($)	Nov. 06, 2012	Jan. 03, 2012	Dec. 31, 2008USD ($)
Loss Contingencies [Line Items]
Number of contract breaches | breach					7
MTBE [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Pending lawsuits and claims (in number of claims) | LegalMatter					7
Ecuador Litigation [Member]
Loss Contingencies [Line Items]
Pending lawsuits and claims (in number of claims) | LegalMatter					9
Remediation program term (in years)					3 years
Ecuador Litigation [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Remediation program term (in years)						3 years
Remediation program						$ 40
Financial compensation for purported damages on mining engineer's report											$ 18,900
Assessment for purported unjust enrichment on mining engineer's report											$ 8,400
Court order requiring the parties to provide their positions on damages within (in days)				45 days
Range of possible loss, minimum			$ 16,000
Range of possible loss, maximum			76,000
Approximate unjust enrichment on plaintiffs' submission, Maximum			38,000
Approximate unjust enrichment on plaintiffs' submission, Minimum			$ 5,000
Amount assessed in damages		$ 8,600					$ 9,500
Amount assessed for plaintiffs representatives		900
Additional amount assessed in punitive damages		$ 8,600
Public apology date within judgment		15 days
Approved court-appointed liquadator's report damages for total judgment	$ 19,100
Litigation Settlement, Amount to be Paid Via Third Party								$ 96
Proposed additional payment for plaintiff attorney fees as percentage of judgment										0.10%
Percentage of payments withheld by third parties due to freeze order									40.00%
Percentage of funds wIthheld by banks due to freeze order									40.00%
Ecuador Litigation [Member] | Declatory Relief Claim [Member]
Loss Contingencies [Line Items]
Pending lawsuits and claims (in number of claims) | LegalMatter					1
Ecuador Litigation [Member] | Discovery Stay On Claims [Member]
Loss Contingencies [Line Items]
Pending lawsuits and claims (in number of claims) | LegalMatter					8

Taxes (Details)

Taxes (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
U.S. federal
Current		$ (817)	$ 748	$ 15
Deferred		(580)	1,330	1,128
State and local
Current		(187)	336	120
Deferred		(109)	36	74
Total United States		(1,693)	2,450	1,337
International
Current		2,997	9,235	12,296
Deferred		(1,172)	207	675
Total International		1,825	9,442	12,971
Total income tax expense (benefit)		$ 132	$ 11,892	$ 14,308
Reconciliation between the U.S. statutory federal income tax rate and the company's effective income tax rate
U.S. statutory federal income tax rate		35.00%	35.00%	35.00%
Effect of income taxes from international operations at rates different from the U.S. statutory rate	[1]	(25.10%)	2.10%	4.40%
State and local taxes on income, net of U.S. federal income tax benefit		(1.50%)	0.70%	0.60%
Tax credits		(0.70%)	(0.20%)	(0.50%)
Other	[1],[2]	(5.00%)	0.50%	0.40%
Effective tax rate		2.70%	38.10%	39.90%
[1]	2013 and 2014 conformed to 2015 presentation.
[2]	2015 includes one-time tax benefits associated with changes in uncertain tax positions and provision-to-return adjustments.

Taxes (Details 1)

Taxes (Details 1) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Deferred tax liabilities
Properties, plant and equipment	$ 27,044	$ 28,452
Investments and other	3,743	3,059
Total deferred tax liabilities	30,787	31,511
Deferred tax assets
Foreign tax credits	(10,534)	(11,867)
Abandonment/environmental reserves	(6,880)	(6,686)
Employee benefits	(4,801)	(4,831)
Deferred credits	(1,810)	(1,828)
Tax loss carryforwards	(2,748)	(1,747)
Other accrued liabilities	(525)	(498)
Inventory	(120)	(153)
Miscellaneous	(2,525)	(2,128)
Total deferred tax assets	(29,943)	(29,738)
Deferred tax assets valuation allowance	15,412	16,292
Total deferred taxes, net	16,256	18,065
Classification of deferred taxes
Prepaid expenses and other current assets	(917)	(1,071)
Deferred charges and other assets	(4,512)	(3,597)
Federal and other taxes on income	996	813
Noncurrent deferred income taxes	20,689	21,920
Total deferred taxes, net	$ 16,256	$ 18,065

Taxes (Details 2)

Taxes (Details 2) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Changes to company's unrecognized tax benefits
Balance at January 1		$ 3,552	$ 3,848	$ 3,071
Foreign currency effects		(27)	(25)	(58)
Additions based on tax positions taken in current year		154	354	276
Additions/reductions resulting from current-year asset acquisitions/sales		0	(22)	0
Additions for tax positions taken in prior years		218	37	1,164
Reductions for tax positions taken in prior years		(678)	(561)	(176)
Settlements with taxing authorities in current year		(5)	(50)	(320)
Reductions as a result of a lapse of the applicable statute of limitations		(172)	(29)	(109)
Balance at December 31		3,042	3,552	3,848
Income Tax Authority [Line Items]
Excise and similar taxes on products and merchandise		7,359	8,186	8,492
Total taxes other than on income	[1]	12,030	12,540	13,063
United States
Income Tax Authority [Line Items]
Excise and similar taxes on products and merchandise		4,426	4,633	4,792
Import duties and other levies		4	6	4
Property and other miscellaneous taxes		1,367	1,002	1,036
Payroll taxes		270	273	255
Taxes on production		157	349	333
Total taxes other than on income		6,224	6,263	6,420
International
Income Tax Authority [Line Items]
Excise and similar taxes on products and merchandise		2,933	3,553	3,700
Import duties and other levies		40	45	41
Property and other miscellaneous taxes		2,548	2,277	2,486
Payroll taxes		161	172	168
Taxes on production		124	230	248
Total taxes other than on income		$ 5,806	$ 6,277	$ 6,643
[1]	Includes excise, value-added and similar taxes. $7,359; $8,186; $8,492.

Taxes (Details Textual)

Taxes (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]
Income before income tax including related corporate and other charges for U.S. operations	$ (2,877)	$ 6,296	$ 4,672
Income before income tax for international operations	7,719	24,906	31,233
Income tax credits and adjustments	$ 35	$ 68	$ 175
Effective tax rate	2.70%	38.10%	39.90%
Approximate decrease in deferred tax liabilities	$ 700
Loss carry forward	7,615
Tax credit carryforward	1,249
Carry forward amount of foreign tax credit with expiration dates	10,534	$ 11,867
Undistributed earnings of international consolidated subsidiaries and affiliates for which no deferred income tax provision has been made for future remittances	$ 45,400
Percentage of impact of unrecognized tax benefits on effective tax rate if subsequently recognized	71.00%
Unrecognized tax benefits	$ 3,042	3,552	$ 3,848	$ 3,071
Income tax accruals for anticipated interest and penalty obligations	399	233
Income tax benefit expense associated with interest and penalties	$ 195	$ 4	$ (42)

Short-Term Debt (Details)

Short-Term Debt (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Short term borrowings
Commercial Paper	[1]	$ 8,252	$ 8,506
Notes payable to banks and others with originating terms of one year or less		20	104
Current maturities of long-term debt		1,487	0
Current maturities of long-term capital leases		17	22
Redeemable long term obligations - Long-term debt		3,152	3,152
Redeemable long term obligations - Capital leases		0	6
Subtotal		12,928	11,790
Reclassified to long-term debt		(8,000)	(8,000)
Total short-term debt		$ 4,928	$ 3,790
[1]	Weighted-average interest rates at December 31, 2015 and 2014, were 0.26 percent and 0.12 percent, respectively.

Short-Term Debt (Details Textua

Short-Term Debt (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Weighted-average interest rates of commercial paper	0.26%	0.12%
Committed credit facilities	$ 8,000
Debt instrument, term	364 days
Reclassified to long-term debt	$ 8,000	$ 8,000
Expiring in December 2017 [Member]
Debt Instrument [Line Items]
Committed credit facilities	$ 6,000
Debt instrument, term	364 days
Expiring in December 2020 [Member]
Debt Instrument [Line Items]
Committed credit facilities	$ 2,000
Debt instrument, term	5 years

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Nov. 30, 2015	Mar. 31, 2015
Debt Instrument [Line Items]
Long-term debt instruments		$ 27,071	$ 15,960
Debt due within one year		(1,487)	0
Reclassified from short-term debt		8,000	8,000
Total long-term debt		33,584	23,960
Long-term debt maturing 2016		1,487
Long-term debt maturing 2017		6,187
Long-term debt maturing 2018		5,836
Long-term debt maturing 2019		2,650
Long-term debt maturing 2020		4,054
Long-term debt maturing after 2020		6,857
Notes Payable [Member] | 3.191% notes due 2023 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 2,250	2,250
Interest rate		3.191%
Notes Payable [Member] | Floating rate notes due 2017 (0.555%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments	[1]	$ 2,050	650
Interest rate		0.555%
Notes Payable [Member] | 1.104% notes due 2017 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 2,000	2,000
Interest rate		1.104%
Notes Payable [Member] | 1.718% notes due 2018 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 2,000	2,000
Interest rate		1.718%
Notes Payable [Member] | 2.355% notes due 2022 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 2,000	2,000
Interest rate		2.355%
Notes Payable [Member] | 1.365% notes due 2018 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,750	0
Interest rate		1.365%
Notes Payable [Member] | 1.961% notes due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,750	0
Interest rate		1.961%
Notes Payable [Member] | 4.95% notes due 2019 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,500	1,500
Interest rate		4.95%
Notes Payable [Member] | 1.790% notes due 2018 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,250	0
Interest rate		1.79%
Notes Payable [Member] | 2.419% notes due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,250	0
Interest rate		2.419%
Notes Payable [Member] | 1.345% notes due 2017 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,100	1,100
Interest rate		1.345%
Notes Payable [Member] | 1.344% notes due 2017 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,000	0
Interest rate		1.344%
Notes Payable [Member] | 2.427% notes due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,000	1,000
Interest rate		2.427%
Notes Payable [Member] | Floating rate notes due 2018 (0.676%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments	[1]	$ 800	0
Interest rate		0.676%
Notes Payable [Member] | 0.889% notes due 2016 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 750	750
Interest rate		0.889%
Notes Payable [Member] | 2.193% notes due 2019 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 750	750
Interest rate		2.193%
Notes Payable [Member] | 3.326% notes due 2025 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 750	0
Interest rate		3.326%
Notes Payable [Member] | 2.411% notes due 2022 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 700	0
Interest rate		2.411%
Notes Payable [Member] | Floating rate notes due 2016 (0.444%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments	[2]	$ 700	700
Interest rate		0.444%
Notes Payable [Member] | Floating rate notes due 2019 (0.772%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments	[2]	$ 400	400
Interest rate		0.772%
Notes Payable [Member] | Floating rate notes due 2021 (0.892%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments	[2]	$ 400	400
Interest rate		0.892%
Notes Payable [Member] | Floating rate notes due 2022 (0.952%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments	[2]	$ 350	0
Interest rate		0.952%
Notes Payable [Member] | Amortizing Bank Loan due 2018 (1.172%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments	[2]	$ 110	0
Interest rate		1.172%
Debentures [Member] | 8.625% debentures due 2032 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 147	147
Interest rate		8.625%
Debentures [Member] | 8.625 % debentures due 2031 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 108	107
Interest rate		8.625%
Debentures [Member] | 8 % debentures due 2032 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 74	74
Interest rate		8.00%
Debentures [Member] | 9.75 % debentures due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 54	54
Interest rate		9.75%
Debentures [Member] | 8.875 % debentures due 2021 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 40	40
Interest rate		8.875%
Medium-term Notes [Member] | Medium-term notes, maturing from 2021 to 2038 (5.83%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments	[1]	$ 38	$ 38
Interest rate		5.975%
Corporate Bond Securities [Member]
Debt Instrument [Line Items]
Debt issued				$ 5,000	$ 6,000
[1]	Weighted-average interest rate at December 31, 2015.
[2]	Interest rate at December 31, 2015.

Accounting for Suspended Expl96

Accounting for Suspended Exploratory Wells (Details) $ in Millions		12 Months Ended
		Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2015USD ($)Project	Dec. 31, 2014USD ($)Project	Dec. 31, 2013USD ($)Project
Changes in company's suspended exploratory well costs
Beginning balance at January 1		$ 4,195	$ 3,245	$ 2,681
Additions to capitalized exploratory well costs pending the determination of proved reserves		869	1,591	885
Reclassifications to wells, facilities and equipment based on the determination of proved reserves		(164)	(298)	(290)
Capitalized exploratory well costs charged to expense		(1,397)	(312)	(31)
Other reductions	[1]	(191)	(31)	0
Ending balance at December 31		3,312	4,195	3,245
Aging of capitalized well costs and number of project
Exploratory well costs capitalized for a period of one year or less					$ 489	$ 1,522	$ 641
Exploratory well costs capitalized for a period greater than one year					2,823	2,673	2,604
Balance at December 31		$ 4,195	$ 3,245	$ 2,681	$ 3,312	$ 4,195	$ 3,245
Number of projects with exploratory well costs that have been capitalized for a period greater than one year | Project	[2]				39	51	51
[1]	Represents property sales.
[2]	Certain projects have multiple wells or fields or both.

Accounting for Suspended Expl97

Accounting for Suspended Exploratory Wells (Details 1) $ in Millions		Dec. 31, 2015USD ($)WellProject	Dec. 31, 2014USD ($)Project	Dec. 31, 2013USD ($)Project
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year		$ 2,823	$ 2,673	$ 2,604
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well		165
Number of projects | Project	[1]	39	51	51
1998–2004 [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year		$ 285
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well		26
2005–2009 [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year		$ 395
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well		33
2010–2014 [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year		$ 2,143
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well		106
2003-2007 [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year		$ 200
Number of projects | Project		4
2008–2011 [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year		$ 393
Number of projects | Project		6
2012–2015 [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year		$ 2,230
Number of projects | Project		29
[1]	Certain projects have multiple wells or fields or both.

Accounting for Suspended Expl98

Accounting for Suspended Exploratory Wells (Details Textual) $ in Millions		12 Months Ended
		Dec. 31, 2015USD ($)WellProject	Dec. 31, 2014USD ($)Project	Dec. 31, 2013USD ($)Project
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year | $		$ 2,823	$ 2,673	$ 2,604
Number of projects with exploratory well costs that have been capitalized for a period greater than one year | Project	[1]	39	51	51
Expected period for decision on the recognition of proved reserves		5 years
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well		165
Drilling Activity [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year | $		$ 1,662
Number of projects with exploratory well costs that have been capitalized for a period greater than one year | Project		20
No Drilling Activity [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year | $		$ 1,161
Number of projects with exploratory well costs that have been capitalized for a period greater than one year | Project		19
Undergoing Front End Engineering and Design with Final Investment Decision Expected [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year | $		$ 190
Number of projects with exploratory well costs that have been capitalized for a period greater than one year | Project		2
Undergoing front-end engineering and design with final investment decision expected in three years		4 years
Development Concept Under Review by Government [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year | $		$ 99
Number of projects with exploratory well costs that have been capitalized for a period greater than one year | Project		1
Reviewing Development Alternatives [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Capitalized exploratory well costs that have been capitalized for period greater than one year | $		$ 814
Number of projects with exploratory well costs that have been capitalized for a period greater than one year | Project		7
Miscellaneous Activities for Projects with Smaller Amounts Suspended [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Number of projects with exploratory well costs that have been capitalized for a period greater than one year | Project		9
Capitalized exploratory well costs that are approved and construction in progress | $		$ 58
[1]	Certain projects have multiple wells or fields or both.

Stock Options and Other Share99

Stock Options and Other Share-Based Compensation (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Stock Option
Expected term in years	[1]	6 years 1 month 6 days	6 years	6 years
Volatility	[2]	21.90%	30.30%	31.30%
Risk-free interest rate based on zero coupon U.S. treasury note		1.40%	1.90%	1.20%
Dividend yield		3.60%	3.30%	3.30%
Weighted-average fair value per option granted		$ 13.89	$ 25.86	$ 24.48
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Outstanding at January 1, 2015		78,341
Shares, Granted (in shares)		22,126
Shares, Exercised (in shares)		(3,104)
Shares, Forfeited (in shares)		(3,071)
Outstanding at December 31, 2015		94,292	78,341
Shares, Exercisable at December 31, 2014 (in shares)		65,657
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price [Roll Forward]
Weighted-Average Exercise Price, Outstanding at January 1, 2014 (in dollars per share)		$ 93.59
Weighted-Average Exercise Price, Granted (in dollars per share)		103.71
Weighted-Average Exercise Price, Exercised (in dollars per share)		62.06
Weighted-Average Exercise Price, Forfeited (in dollars per share)		103.70
Weighted-Average Exercise Price, Outstanding at December 31, 2014 (in dollars per share)		96.67	$ 93.59
Weighted-Average Exercise Price, Exercisable at December 31, 2014 (in dollars per share)		$ 91.85
Average Remaining Contractual Term, Outstanding at December 31, 2014 (in years)		5 years 9 months 29 days
Average Remaining Contractual Term, Exercisable at December 31, 2014 (in years)		4 years 7 months 10 days
Aggregate Intrinsic Value, Outstanding at December 31, 2014		$ 467
Aggregate Intrinsic Value, Exercisable at December 31, 2014		$ 467
[1]	Expected term is based on historical exercise and postvesting cancellation data.
[2]	Volatility rate is based on historical stock prices over an appropriate period, generally equal to the expected term.

Stock Options and Other Shar100

Stock Options and Other Share-Based Compensation (Details 1) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense for stock options	$ 312	$ 287	$ 292
After tax compensation expense for stock options	203	186	190
Compensation expense for stock appreciation rights restricted stock performance units and restricted stock units	32	71	223
Compensation expense for stock appreciation rights, restricted stock, performance units and restricted stock units, after tax	21	46	145
Cash received in payment for option exercises	195	527	553
Tax benefits realized for the tax deductions from option exercises	17	54	73
Cash paid to settle performance units and stock appreciation rights	$ 104	204	186
Maximum number of share that may be issued under LTIP (in shares)	120,753
Total intrinsic value options exercised	$ 120	$ 398	$ 445
Total before-tax compensation cost related to nonvested share-based compensation arrangements	$ 190
Weighted-average period of recognition of unrecognized compensation cost related to nonvested share-based compensation arrangements	1 year 8 months 12 days
Number of LTIP performance units outstanding (in shares)	2,192,937	2,265,952
Number of LTIP performance units granted (in shares)	890,000
Number of LTIP performance units vested outstanding (in shares)	828,868
Number of LTIP performance units forfeited (in shares)	134,147
Fair value of the liability recorded for LTIP performance units outstanding	$ 166
Equivalent shares granted under various LTIP and former Texaco and Unocal programs for outstanding stock appreciation rights and other awards	4,500,000
Liability recorded for Equivalent shares granted under various LTIP and former Texaco and Unocal programs for outstanding stock appreciation rights and other awards	$ 51
Chevron Long-Term Incentive Plan (LTIP) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum number of share that may be issued under LTIP (in shares)	114,000,000
For awards issued on or after May 29, 2013, the maximum number of shares that may be in a form other than a stock option, stock appreciation right or award requiring full payment for shares by the award recipient (in shares)	50,000,000
Chevron Long-Term Incentive Plan (LTIP) [Member] | Maximum [Member] | From April 2004 through May 2023 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum number of share that may be issued under LTIP (in shares)	260,000,000
Performance Shares [Member] | Chevron Long-Term Incentive Plan (LTIP) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award contractual term (in years)	3 years
Stock Options and Stock Appreciation Rights [Member] | Chevron Long-Term Incentive Plan (LTIP) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award contractual term (in years)	10 years

Employee Benefit Plans (Details

Employee Benefit Plans (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
U.S. [Member]
Change in Benefit Obligation
Benefit obligation at January 1	$ 14,250	$ 12,080
Service cost	538	450	$ 495
Interest cost	502	494	471
Plan participants' contributions	0	0
Plan amendments	0	0
Actuarial (gain) loss	(345)	2,299
Foreign currency exchange rate changes	0	0
Benefits paid	(1,382)	(1,073)
Divestitures	0	0
Curtailment	0	0
Benefit obligation at December 31	13,563	14,250	12,080
Change in Plan Assets
Fair value of plan assets at January 1	11,090	11,210
Actual return on plan assets	(75)	854
Foreign currency exchange rate changes	0	0
Employer contributions	641	99
Plan participants' contributions	0	0
Benefits paid	(1,382)	(1,073)
Divestitures	0	0
Fair value of plan assets at December 31	10,274	11,090	11,210
Funded Status at December 31	(3,289)	(3,160)
International [Member]
Change in Benefit Obligation
Benefit obligation at January 1	5,767	6,095
Service cost	185	190	197
Interest cost	277	340	314
Plan participants' contributions	6	8
Plan amendments	(6)	3
Actuarial (gain) loss	(309)	336
Foreign currency exchange rate changes	(326)	(348)
Benefits paid	(241)	(293)
Divestitures	0	(564)
Curtailment	(17)	0
Benefit obligation at December 31	5,336	5,767	6,095
Change in Plan Assets
Fair value of plan assets at January 1	4,244	4,543
Actual return on plan assets	112	571
Foreign currency exchange rate changes	(239)	(279)
Employer contributions	227	276
Plan participants' contributions	6	8
Benefits paid	(241)	(293)
Divestitures	0	(582)
Fair value of plan assets at December 31	4,109	4,244	4,543
Funded Status at December 31	(1,227)	(1,523)
Other Benefits [Member]
Change in Benefit Obligation
Benefit obligation at January 1	3,660	3,138
Service cost	72	50	66
Interest cost	151	148	149
Plan participants' contributions	148	150
Plan amendments	0	2
Actuarial (gain) loss	(326)	544
Foreign currency exchange rate changes	(37)	(22)
Benefits paid	(344)	(350)
Divestitures	0	0
Curtailment	0	0
Benefit obligation at December 31	3,324	3,660	3,138
Change in Plan Assets
Fair value of plan assets at January 1	0	0
Actual return on plan assets	0	0
Foreign currency exchange rate changes	0	0
Employer contributions	196	200
Plan participants' contributions	148	150
Benefits paid	(344)	(350)
Divestitures	0	0
Fair value of plan assets at December 31	0	0	$ 0
Funded Status at December 31	$ (3,324)	$ (3,660)

Employee Benefit Plans (Deta102

Employee Benefit Plans (Details 1) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Consolidated Balance Sheet for pension and other postretirement benefit plans
Noncurrent employee benefit plans	$ (7,935)	$ (8,412)
U.S. [Member]
Consolidated Balance Sheet for pension and other postretirement benefit plans
Deferred charges and other assets	13	13
Accrued liabilities	(153)	(123)
Noncurrent employee benefit plans	(3,149)	(3,050)
Net amount recognized at December 31	(3,289)	(3,160)
International [Member]
Consolidated Balance Sheet for pension and other postretirement benefit plans
Deferred charges and other assets	333	244
Accrued liabilities	(77)	(68)
Noncurrent employee benefit plans	(1,483)	(1,699)
Net amount recognized at December 31	(1,227)	(1,523)
Other Benefits [Member]
Consolidated Balance Sheet for pension and other postretirement benefit plans
Deferred charges and other assets	0	0
Accrued liabilities	(191)	(198)
Noncurrent employee benefit plans	(3,133)	(3,462)
Net amount recognized at December 31	$ (3,324)	$ (3,660)

Employee Benefit Plans (Deta103

Employee Benefit Plans (Details 2) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Before tax basis amount in accumulated other comprehensive loss.
Total recognized at December 31	$ 6,478	$ 7,417
U.S. [Member]
Before tax basis amount in accumulated other comprehensive loss.
Net actuarial loss	4,809	4,972
Prior service (credit) costs	(5)	(13)
Total recognized at December 31	4,804	4,959
International [Member]
Before tax basis amount in accumulated other comprehensive loss.
Net actuarial loss	1,143	1,487
Prior service (credit) costs	120	150
Total recognized at December 31	1,263	1,637
Other Benefits [Member]
Before tax basis amount in accumulated other comprehensive loss.
Net actuarial loss	367	763
Prior service (credit) costs	44	58
Total recognized at December 31	$ 411	$ 821

Employee Benefit Plans (Deta104

Employee Benefit Plans (Details 3) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
U.S. [Member]
Pension Plans With Accumulated Benefit Obligation in Excess of Plan Assets
Projected benefit obligations	$ 13,500	$ 14,182
Accumulated benefit obligations	11,969	12,765
Fair value of plan assets	10,198	11,009
International [Member]
Pension Plans With Accumulated Benefit Obligation in Excess of Plan Assets
Projected benefit obligations	1,623	1,938
Accumulated benefit obligations	1,357	1,525
Fair value of plan assets	$ 207	$ 262

Employee Benefit Plans (Deta105

Employee Benefit Plans (Details 4) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Changes Recognized in Comprehensive Income
Prior service (credits) costs during period	$ (6)	$ 6	$ (60)
Amortization of prior service (costs) credits	(30)	(26)	27
U.S. [Member]
Net Periodic Benefit Cost
Service cost	538	450	495
Interest cost	502	494	471
Expected return on plan assets	(783)	(788)	(701)
Amortization of prior service costs (credits)	(8)	(9)	2
Recognized actuarial losses	356	209	485
Settlement losses	320	237	173
Curtailment losses (gains)	0	0	0
Total net periodic benefit cost	925	593	925
Changes Recognized in Comprehensive Income
Net actuarial (gain) loss during period	513	2,233	(2,244)
Amortization of actuarial loss	(676)	(446)	(658)
Prior service (credits) costs during period	0	0	(78)
Amortization of prior service (costs) credits	8	9	(2)
Total changes recognized in other comprehensive income	(155)	1,796	(2,982)
Recognized in Net Periodic Benefit Cost and Other Comprehensive Income	770	2,389	(2,057)
International [Member]
Net Periodic Benefit Cost
Service cost	185	190	197
Interest cost	277	340	314
Expected return on plan assets	(262)	(298)	(274)
Amortization of prior service costs (credits)	22	21	21
Recognized actuarial losses	78	96	143
Settlement losses	6	208	12
Curtailment losses (gains)	(14)	0	0
Total net periodic benefit cost	292	557	413
Changes Recognized in Comprehensive Income
Net actuarial (gain) loss during period	(260)	(17)	(476)
Amortization of actuarial loss	(84)	(304)	(155)
Prior service (credits) costs during period	(6)	4	18
Amortization of prior service (costs) credits	(24)	(21)	(21)
Total changes recognized in other comprehensive income	(374)	(338)	(634)
Recognized in Net Periodic Benefit Cost and Other Comprehensive Income	(82)	219	(221)
Other Benefits [Member]
Net Periodic Benefit Cost
Service cost	72	50	66
Interest cost	151	148	149
Expected return on plan assets	0	0	0
Amortization of prior service costs (credits)	14	14	(50)
Recognized actuarial losses	34	7	53
Settlement losses	0	0	0
Curtailment losses (gains)	0	0	0
Total net periodic benefit cost	271	219	218
Changes Recognized in Comprehensive Income
Net actuarial (gain) loss during period	(362)	514	(659)
Amortization of actuarial loss	(34)	(7)	(53)
Prior service (credits) costs during period	0	2	0
Amortization of prior service (costs) credits	(14)	(14)	50
Total changes recognized in other comprehensive income	(410)	495	(662)
Recognized in Net Periodic Benefit Cost and Other Comprehensive Income	$ (139)	$ 714	$ (444)

Employee Benefit Plans (Deta106

Employee Benefit Plans (Details 5) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Effects of change in the assumed health care cost-trend rates
Effect on total service and interest cost components, 1 Percent Increase	$ 20
Effect on total service and interest cost components, 1 Percent Decrease	(17)
Effect on postretirement benefit obligation, 1 Percent Increase	192
Effect on postretirement benefit obligation, 1 Percent Decrease	$ (164)
U.S. [Member]
Assumptions used to determine benefit obligations:
Discount rate	4.00%	3.70%	4.30%
Rate of compensation increase	4.50%	4.50%	4.50%
Assumptions used to determine net periodic benefit cost:
Discount rate	3.70%	4.30%	3.60%
Expected return on plan assets	7.50%	7.50%	7.50%
Rate of compensation increase	4.50%	4.50%	4.50%
International [Member]
Assumptions used to determine benefit obligations:
Discount rate	5.30%	5.00%	5.80%
Rate of compensation increase	4.80%	5.10%	5.50%
Assumptions used to determine net periodic benefit cost:
Discount rate	5.00%	5.80%	5.20%
Expected return on plan assets	6.30%	6.60%	6.80%
Rate of compensation increase	5.10%	5.50%	5.50%
Other Benefits [Member]
Assumptions used to determine benefit obligations:
Discount rate	4.60%	4.30%	4.90%
Assumptions used to determine net periodic benefit cost:
Discount rate	4.30%	4.90%	4.10%

Employee Benefit Plans (Deta107

Employee Benefit Plans (Details 6) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Fair Value Measurements of Company's Pension Plans
Investment in company's common stock		$ 9	$ 24
U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		10,274	11,090	$ 11,210
U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		3,306	3,720
U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		5,422	5,952
U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1,546	1,418
International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		4,109	4,244	$ 4,543
International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1,196	1,014
International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		2,508	2,876
International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		405	354
U.S equity [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[1]	1,699	2,087
U.S equity [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[1]	1,699	2,087
U.S equity [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[1]	0	0
U.S equity [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[1]	0	0
U.S equity [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[1]	392	241
U.S equity [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[1]	382	241
U.S equity [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[1]	10	0
U.S equity [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[1]	0	0
International Equity Securities [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1,302	1,297
International Equity Securities [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1,296	1,297
International Equity Securities [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		6	0
International Equity Securities [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
International Equity Securities [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		457	313
International Equity Securities [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		435	313
International Equity Securities [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		22	0
International Equity Securities [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Collective Trusts Mutual Funds Equity [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	2,460	3,240
Collective Trusts Mutual Funds Equity [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	18	22
Collective Trusts Mutual Funds Equity [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	2,442	3,218
Collective Trusts Mutual Funds Equity [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	0	0
Collective Trusts Mutual Funds Equity [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	572	979
Collective Trusts Mutual Funds Equity [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	7	173
Collective Trusts Mutual Funds Equity [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	565	806
Collective Trusts Mutual Funds Equity [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	0	0
Government [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		257	84
Government [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		46	47
Government [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		211	37
Government [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Government [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1,089	1,066
Government [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		93	53
Government [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		996	1,013
Government [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Corporate [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1,654	1,502
Corporate [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Corporate [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1,654	1,502
Corporate [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Corporate [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		615	585
Corporate [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		33	26
Corporate [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		557	537
Corporate [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		25	22
Bank Loans [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		148
Bank Loans [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0
Bank Loans [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		148
Bank Loans [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0
Bank Loans [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0
Bank Loans [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0
Bank Loans [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0
Bank Loans [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0
Mortgage-Backed Securities [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1	1
Mortgage-Backed Securities [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Mortgage-Backed Securities [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1	1
Mortgage-Backed Securities [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Mortgage-Backed Securities [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1	1
Mortgage-Backed Securities [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Mortgage-Backed Securities [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1	1
Mortgage-Backed Securities [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Other Asset Backed [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1	0
Other Asset Backed [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Other Asset Backed [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		1	0
Other Asset Backed [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Other Asset Backed [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Other Asset Backed [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Other Asset Backed [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Other Asset Backed [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Collective Trusts/Mutual Funds [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	933	1,174
Collective Trusts/Mutual Funds [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	0	0
Collective Trusts/Mutual Funds [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	933	1,174
Collective Trusts/Mutual Funds [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	0	0
Collective Trusts/Mutual Funds [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	269	394
Collective Trusts/Mutual Funds [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	12	16
Collective Trusts/Mutual Funds [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	257	378
Collective Trusts/Mutual Funds [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[2]	0	0
Mixed Funds [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[3]	0	0
Mixed Funds [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[3]	0	0
Mixed Funds [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[3]	0	0
Mixed Funds [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[3]	0	0
Mixed Funds [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[3]	85	122
Mixed Funds [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[3]	4	3
Mixed Funds [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[3]	81	119
Mixed Funds [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[3]	0	0
Real Estate [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[4]	1,494	1,364
Real Estate [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[4]	0	0
Real Estate [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[4]	0	0
Real Estate [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[4]	1,494	1,364
Real Estate [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[4]	378	329
Real Estate [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[4]	0	0
Real Estate [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[4]	0	0
Real Estate [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[4]	378	329
Cash And Cash Equivalents [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		253	270
Cash And Cash Equivalents [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		253	270
Cash And Cash Equivalents [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Cash And Cash Equivalents [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Cash And Cash Equivalents [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		232	190
Cash And Cash Equivalents [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		232	189
Cash And Cash Equivalents [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	1
Cash And Cash Equivalents [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets		0	0
Other [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[5]	72	71
Other [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[5]	(6)	(3)
Other [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[5]	26	20
Other [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[5]	52	54
Other [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[5]	19	24
Other [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[5]	(2)	0
Other [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[5]	19	21
Other [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	[5]	$ 2	$ 3
[1]	U.S. equities include investments in the company’s common stock in the amount of $9 at December 31, 2015, and $24 at December 31, 2014.
[2]	Collective Trusts/Mutual Funds for U.S. plans are entirely index funds; for International plans, they are mostly index funds. For these index funds, the Level 2 designation is partially based on the restriction that advance notification of redemptions, typically two business days, is required.
[3]	Mixed funds are composed of funds that invest in both equity and fixed-income instruments in order to diversify and lower risk.
[4]	The year-end valuations of the U.S. real estate assets are based on internal appraisals by the real estate managers, which are updates of third-party appraisals that occur at least once a year for each property in the portfolio.
[5]	The “Other” asset class includes net payables for securities purchased but not yet settled (Level 1); dividends and interest- and tax-related receivables (Level 2); insurance contracts and investments in private-equity limited partnerships (Level 3).

Employee Benefit Plans (Deta108

Employee Benefit Plans (Details 7) - Level 3 [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
The effect of fair-value measurements using significant unobservable inputs on changes in Level 3 plan assets for the period are outlined below
Beginning Balance	$ 1,772	$ 1,641
Actual Return on Plan Assets:
Assets held at the reporting date	145	115
Assets sold during the period	23	20
Purchases, Sales and Settlements	11	(4)
Transfers in and/or out of Level 3	0	0
Ending Balance	1,951	1,772
Corporate [Member]
The effect of fair-value measurements using significant unobservable inputs on changes in Level 3 plan assets for the period are outlined below
Beginning Balance	22	23
Actual Return on Plan Assets:
Assets held at the reporting date	(3)	0
Assets sold during the period	0	0
Purchases, Sales and Settlements	6	(1)
Transfers in and/or out of Level 3	0	0
Ending Balance	25	22
Mortgage-Backed Securities [Member]
The effect of fair-value measurements using significant unobservable inputs on changes in Level 3 plan assets for the period are outlined below
Beginning Balance	0	2
Actual Return on Plan Assets:
Assets held at the reporting date	0	0
Assets sold during the period	0	0
Purchases, Sales and Settlements	0	(2)
Transfers in and/or out of Level 3	0	0
Ending Balance	0	0
Real Estate [Member]
The effect of fair-value measurements using significant unobservable inputs on changes in Level 3 plan assets for the period are outlined below
Beginning Balance	1,693	1,559
Actual Return on Plan Assets:
Assets held at the reporting date	149	115
Assets sold during the period	23	20
Purchases, Sales and Settlements	7	(1)
Transfers in and/or out of Level 3	0	0
Ending Balance	1,872	1,693
Other [Member]
The effect of fair-value measurements using significant unobservable inputs on changes in Level 3 plan assets for the period are outlined below
Beginning Balance	57	57
Actual Return on Plan Assets:
Assets held at the reporting date	(1)	0
Assets sold during the period	0	0
Purchases, Sales and Settlements	(2)	0
Transfers in and/or out of Level 3	0	0
Ending Balance	$ 54	$ 57

Employee Benefit Plans (Deta109

Employee Benefit Plans (Details 8) $ in Millions	Dec. 31, 2015USD ($)
U.S. [Member]
Benefit payments, which include estimated future service, are expected to be paid by the company in the next 10years
2,016	$ 1,462
2,017	1,384
2,018	1,360
2,019	1,329
2,020	1,287
2021-2025	5,804
International [Member]
Benefit payments, which include estimated future service, are expected to be paid by the company in the next 10years
2,016	284
2,017	297
2,018	467
2,019	339
2,020	346
2021-2025	1,822
Other Benefits [Member]
Benefit payments, which include estimated future service, are expected to be paid by the company in the next 10years
2,016	191
2,017	195
2,018	199
2,019	203
2,020	207
2021-2025	$ 1,053

Employee Benefit Plans (Deta110

Employee Benefit Plans (Details Textual) - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Maximum annual increase percentage to company contribution for retiree medical coverage	4.00%
Funded Status:
Amounts recognized on a before-tax bases in "Accumulated other comprehensive loss" for the company's pension and other postretirement benefit plans	$ 6,478	$ 7,417
Net Actuarial Loss:
The percentage of the higher of the projected benefit obligation or market-related value of plan assets in excess of which net actuarial losses are amortized	10.00%
Other Benefit Assumptions:
Assumed health care cost-trend rates in the next fiscal year	7.10%	7.00%
Ultimate trend rate for health care cost	4.50%	4.50%
Year when the ultimate health care cost trend rate is expected to be reached	2,025	2,025
Maximum annual increase in contribution rate in post retirement benefit	4.00%
Primary Investment:
Company's US and UK pension plans as a percentage of total pension assets	91.00%
Benefit Plan Trusts:
Number of Chevron treasury stocks held in benefit plan trust for funding obligations	14.2
Various grantor trust assets invested primarily in interest earning accounts	$ 36	$ 38
Employee Incentive Plan
Charges to expense for cash bonuses	690	965	$ 871
U.S. [Member]
Funded Status:
Amounts recognized on a before-tax bases in "Accumulated other comprehensive loss" for the company's pension and other postretirement benefit plans	4,804	4,959
Accumulated benefit obligations pension plans	$ 12,032	$ 12,833
Net Actuarial Loss:
Number of years net actuarial losses recorded in "Accumulated other comprehensive loss" at December 31 for the company's US pension plans are being amortized for, over a straight-line basis	10 years
Actuarial gain (loss) that will be amortized from Accumulated other comprehensive loss	$ 335
Company's estimated amount that will be recognized from "Accumulated other comprehensive loss" during the next year related to lump-sum settlement costs from U.S. pension plans	$ 324
Weighted average amortization period (in years) for recognizing prior service costs (credits) recorded in "Accumulated other comprehensive loss" at December 31 for US pension plan	4 years
Amortization of prior service (credits) costs during the next year	$ (9)
Expected Return on Plan Assets:
Estimated long-term rate of return on US pension plan assets	7.50%	7.50%	7.50%
Percentage of US pension plan assets relative to total pension plan assets	71.00%
Plan asset market valuation period, prior to year-end measurement date	3 months
Discount Rate:
Discount rate for pension plans	4.00%	3.70%	4.30%
Cash Contributions and Benefit Payments:
Contributions to employee pension plans	$ 641	$ 99
Estimated contributions to employee pension plans for the next fiscal year	$ 650
U.S. [Member] | Equities [Member]
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation, minimum	40.00%
Pension Plan - Board of Trustees approved asset allocation, maximum	70.00%
U.S. [Member] | Fixed Income and Cash [Member]
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation, minimum	20.00%
Pension Plan - Board of Trustees approved asset allocation, maximum	60.00%
U.S. [Member] | Real Estate [Member]
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation, minimum	0.00%
Pension Plan - Board of Trustees approved asset allocation, maximum	15.00%
U.S. [Member] | Other [Member]
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation, minimum	0.00%
Pension Plan - Board of Trustees approved asset allocation, maximum	5.00%
International [Member]
Funded Status:
Amounts recognized on a before-tax bases in "Accumulated other comprehensive loss" for the company's pension and other postretirement benefit plans	$ 1,263	1,637
Accumulated benefit obligations pension plans	$ 4,684	$ 4,995
Net Actuarial Loss:
Number of years net actuarial losses recorded in "Accumulated other comprehensive loss" at December 31 for the company's international pension plans are being amortized for, over a straight-line basis	10 years
Actuarial gain (loss) that will be amortized from Accumulated other comprehensive loss	$ 56
Weighted average amortization period (in years) for recognizing prior service costs (credits) recorded in "Accumulated other comprehensive loss" at December 31 for international pension plan	11 years
Amortization of prior service (credits) costs during the next year	$ 15
Expected Return on Plan Assets:
Estimated long-term rate of return on US pension plan assets	6.30%	6.60%	6.80%
Discount Rate:
Discount rate for pension plans	5.30%	5.00%	5.80%
Cash Contributions and Benefit Payments:
Contributions to employee pension plans	$ 227	$ 276
Estimated contributions to employee pension plans for the next fiscal year	250
International [Member] | Including Portion Funded by Third Party [Member]
Cash Contributions and Benefit Payments:
Contributions to employee pension plans	$ 227
International [Member] | Equities [Member] | UNITED KINGDOM [Member]
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation, minimum	30.00%
Pension Plan - Board of Trustees approved asset allocation, maximum	50.00%
International [Member] | Fixed Income and Cash [Member] | UNITED KINGDOM [Member]
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation, minimum	35.00%
Pension Plan - Board of Trustees approved asset allocation, maximum	65.00%
International [Member] | Real Estate [Member] | UNITED KINGDOM [Member]
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation, minimum	5.00%
Pension Plan - Board of Trustees approved asset allocation, maximum	15.00%
United States Postretirement Benefit Plan of US Entity [Member]
Discount Rate:
Discount rate for pension plans	4.50%	4.10%	4.70%
Other Benefits [Member]
Funded Status:
Amounts recognized on a before-tax bases in "Accumulated other comprehensive loss" for the company's pension and other postretirement benefit plans	$ 411	$ 821
Net Actuarial Loss:
Number of years net actuarial losses recorded in "Accumulated other comprehensive loss" at December 31 for the company's OPEB plans are being amortized for, over a straight-line basis	16 years
Actuarial gain (loss) that will be amortized from Accumulated other comprehensive loss	$ 19
Weighted average amortization period (in years) for recognizing prior service costs (credits) recorded in "Accumulated other comprehensive loss" at December 31 for other postretirement benefit plan	7 years
Amortization of prior service (credits) costs during the next year	$ 14
Discount Rate:
Discount rate for pension plans	4.60%	4.30%	4.90%
Cash Contributions and Benefit Payments:
Contributions to employee pension plans	$ 196	$ 200
Estimated contributions to employee pension plans for the next fiscal year	191
ESIP [Member]
Employee Savings Investment Plan:
Compensation expense	$ 316	$ 316	$ 163
Value of shares released from LESOP to reduce cost of total company matching contributions to employee accounts within ESIP			$ 140

Other Contingencies and Comm111

Other Contingencies and Commitments (Details)	Nov. 07, 2011bbl	Dec. 31, 2015USD ($)Location	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Aug. 27, 2015Employee	Mar. 14, 2012Employee	Dec. 31, 2009USD ($)
Guarantees
Guarantee for payments under terminal use agreements		$ 447,000,000
Term of guarantee for payments under terminal use agreement (in years)		12 years
Idemnifications
Indemnifications acquirer environmental liabilities, maximum obligation							$ 200,000,000
Long-Term Unconditional Purchase Obligations and Commitments, Including Throughput and Take-or-Pay Agreements
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2016		$ 2,100,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2017		1,900,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2018		1,700,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2019		1,500,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2020		1,100,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2020 and after		3,100,000,000
Total payments under long term unconditional purchase obligations and commitments including throughput and Take-or-Pay agreements		1,900,000,000	$ 3,700,000,000	$ 3,600,000,000
Environmental
Environmental reserve balance		$ 1,578,000,000
Sites with potential remediation activities | Location		163
Criminal charges, number of employees charged | Employee						11
Dismissal of charges, number of employees | Employee					11
BRAZIL
Environmental
Emitted of barrels of oil | bbl	2,400
Upstream [Member]
Environmental
Environmental reserve		$ 323,000,000
U.S. Downstream [Member]
Environmental
Environmental reserve		845,000,000
International Downstream [Member]
Environmental
Environmental reserve		58,000,000
Other Businesses [Member]
Environmental
Environmental reserve		4,000,000
Sites with Potential Remediation Activities [Member]
Environmental
Environmental reserve		348,000,000
Environmental Reserve Less Environmental Reserve for Sites with Potential Remediation Activities [Member]
Environmental
Environmental reserve		$ 1,230,000,000

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Company Before Tax Obligation
Balance at January 1	$ 15,053	$ 14,298	$ 13,271
Liabilities incurred	51	133	59
Liabilities settled	(981)	(1,291)	(907)
Accretion expense	715	882	627
Revisions in estimated cash flows	804	1,031	1,248
Balance at December 31	15,642	$ 15,053	$ 14,298
Long-term portion of the company's before-tax asset retirement obligations	$ 14,892

Restructuring and Reorganiza113

Restructuring and Reorganization Costs (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Restructuring Cost and Reserve [Line Items]
Before tax charge	$ 353
After tax charge	223
Payments for Restructuring	60
Restructuring Reserve [Roll Forward]
Balance at January 1, 2015	0
Accruals/Adjustments	353
Payments	(60)
Balance at December 31, 2015	293
Corporate, Non-Segment [Member]
Restructuring Cost and Reserve [Line Items]
Before tax charge	134
After tax charge	87
United States [Member] | Upstream [Member]
Restructuring Cost and Reserve [Line Items]
Before tax charge	113
After tax charge	73
International [Member] | Upstream [Member]
Restructuring Cost and Reserve [Line Items]
Before tax charge	106
After tax charge	63
Operating Expense [Member]
Restructuring Cost and Reserve [Line Items]
Before tax charge	219
Selling, General and Administrative Expenses [Member]
Restructuring Cost and Reserve [Line Items]
Before tax charge	$ 134

Other Financial Information (De

Other Financial Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Segment Reporting Information [Line Items]
Total financing interest and debt costs		$ 495	$ 358		$ 284
Less: Capitalized interest		495	358		284
Interest and debt expense		0	0		0
Research and development expenses		601	707		750
Excess of replacement cost over the carrying value of inventories (LIFO method)		3,745	8,135		9,150
LIFO (losses) / profits on inventory drawdowns included in earnings		(65)	13		14
Foreign currency effects	[1]	769	487		474
Gains on sale of nonstrategic properties		2,300	3,000
Gain (loss) for impairments and other assets write-offs		3,000	1,000
Company share of equity affiliates foreign currency effects		344	118		$ 244
Goodwill		4,588	4,593	[2]
Other Assets and Investments [Member]
Segment Reporting Information [Line Items]
Gain (loss) for impairments and other assets write-offs			200
Downstream [Member]
Segment Reporting Information [Line Items]
Gains on sale of nonstrategic properties		1,800	1,000
Upstream [Member]
Segment Reporting Information [Line Items]
Gains on sale of nonstrategic properties		$ 500	1,800
Gain (loss) for impairments and other assets write-offs			$ 800
[1]	Includes $344, $118 and $244 in 2015, 2014 and 2013, respectively, for the company’s share of equity affiliates’ foreign currency effects.
[2]	2014 conformed to 2015 presentation

Schedule II - Valuation and 115

Schedule II - Valuation and Qualifying Accounts (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Employee Termination Benefits [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at January 1		$ 49	$ 14	$ 30
Additions (reductions) charged to expense		342	53	(6)
Payments		(83)	(18)	(10)
Balance at December 31		308	49	14
Allowance for Doubtful Accounts [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at January 1		194	95	155
Additions (reductions) charged to expense		251	119	1
Bad debt write-offs		(16)	(20)	(61)
Balance at December 31		429	194	95
Deferred Income Tax Valuation Allowance [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at January 1	[1]	16,292	17,171	15,443
Additions to deferred income tax expense	[1]	1,440	1,192	2,665
Reduction of deferred income tax expense	[1]	(2,320)	(2,071)	(937)
Balance at December 31	[1]	$ 15,412	$ 16,292	$ 17,171
[1]	See also Note 18 to the Consolidated Financial Statements, beginning on page FS-45.