Chevron (CVX) 10-K 23 Feb 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2016	Feb. 15, 2017	Jun. 30, 2016
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, 2016
Amendment Flag	false
Document Fiscal Year Focus	2,016
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			$ 197,763,938,564
Entity Common Stock, Shares Outstanding		1,893,102,970

Consolidated Statement of Incom

Consolidated Statement of Income - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Revenues and Other Income
Sales and other operating revenues	[1]	$ 110,215	$ 129,925	$ 200,494
Income from equity affiliates		2,661	4,684	7,098
Other income		1,596	3,868	4,378
Total Revenues and Other Income		114,472	138,477	211,970
Costs and Other Deductions
Purchased crude oil and products		59,321	69,751	119,671
Operating expenses		20,268	23,034	25,285
Selling, general and administrative expenses		4,684	4,443	4,494
Exploration expenses		1,033	3,340	1,985
Depreciation, depletion and amortization		19,457	21,037	16,793
Taxes other than on income	[1]	11,668	12,030	12,540
Interest and debt expense		201	0	0
Total Costs and Other Deductions		116,632	133,635	180,768
Income (Loss) Before Income Tax Expense		(2,160)	4,842	31,202
Income Tax Expense (Benefit)		(1,729)	132	11,892
Net Income (Loss)		(431)	4,710	19,310
Less: Net income attributable to noncontrolling interests		66	123	69
Net Income (Loss) Attributable to Chevron Corporation		$ (497)	$ 4,587	$ 19,241
Net Income (Loss) Attributable to Chevron Corporation
– Basic (in dollars per share)		$ (0.27)	$ 2.46	$ 10.21
– Diluted (in dollars per share)		$ (0.27)	$ 2.45	$ 10.14
[1]	Includes excise, value-added and similar taxes. $6,905; $7,359; $8,186.

Consolidated Statement of Inco3

Consolidated Statement of Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Statement [Abstract]
Includes excise, value-added and similar taxes	$ 6,905	$ 7,359	$ 8,186

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement of Comprehensive Income [Abstract]
Net Income (Loss)	$ (431)	$ 4,710	$ 19,310
Currency translation adjustment
Unrealized net change arising during period	(22)	(44)	(73)
Unrealized holding gain (loss) on securities
Net gain (loss) arising during period	27	(21)	(2)
Derivatives
Net derivatives loss on hedge transactions	0	0	(66)
Reclassification to net income of net realized (gain) loss	0	0	(17)
Income taxes on derivatives transactions	0	0	29
Total	0	0	(54)
Actuarial gain (loss)
Amortization to net income of net actuarial loss and settlements	918	794	757
Actuarial gain (loss) arising during period	(315)	109	(2,730)
Prior service credits (cost)
Amortization to net income of net prior service costs and curtailments	19	30	26
Prior service credits (costs) arising during period	345	6	(6)
Defined benefit plans sponsored by equity affiliates - (cost) benefit	(19)	30	(99)
Income taxes on defined benefit plans	(505)	(336)	901
Total	443	633	(1,151)
Other Comprehensive Gain (Loss), Net of Tax	448	568	(1,280)
Comprehensive Income (Loss)	17	5,278	18,030
Comprehensive income attributable to noncontrolling interests	(66)	(123)	(69)
Comprehensive Income (Loss) Attributable to Chevron Corporation	$ (49)	$ 5,155	$ 17,961

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Assets
Cash and cash equivalents		$ 6,988	$ 11,022
Marketable securities		13	310
Accounts and notes receivable (less allowance: 2016 - $373; 2015 - $313)		14,092	12,860
Inventories:
Crude oil and petroleum products		2,720	3,535
Chemicals		455	490
Materials, supplies and other		2,244	2,309
Total inventories		5,419	6,334
Prepaid expenses and other current assets	[1]	3,107	3,904
Total Current Assets		29,619	34,430
Long-term receivables, net		2,485	2,412
Investments and advances		30,250	27,110
Properties, plant and equipment, at cost		336,077	340,277
Less: Accumulated depreciation, depletion and amortization		153,891	151,881
Properties, plant and equipment, net		182,186	188,396
Deferred charges and other assets	[1],[2]	6,838	6,155
Goodwill		4,581	4,588
Assets held for sale		4,119	1,449
Total Assets		260,078	264,540
Liabilities and Equity
Short-term debt (net of unamortized discount and debt issuance costs: $3 in 2016, $1 in 2015)	[2]	10,840	4,927
Accounts payable		13,986	13,516
Accrued liabilities		4,882	4,833
Federal and other taxes on income	[1]	1,050	1,073
Other taxes payable		1,027	1,118
Total Current Liabilities		31,785	25,467
Long-term debt (net of unamortized discount and debt issuance costs: $41 in 2016, $42 in 2015)	[2]	35,193	33,542
Capital lease obligations		93	80
Deferred credits and other noncurrent obligations		21,553	23,465
Noncurrent deferred income taxes	[1]	17,516	20,165
Noncurrent employee benefit plans		7,216	7,935
Total Liabilities	[3]	113,356	110,654
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, 2016 and 2015)		1,832	1,832
Capital in excess of par value		16,595	16,330
Retained earnings		173,046	181,578
Accumulated other comprehensive loss		(3,843)	(4,291)
Deferred compensation and benefit plan trust		(240)	(240)
Treasury stock, at cost (2016 - 551,170,158 shares; 2015 - 559,862,580 shares)		(41,834)	(42,493)
Total Chevron Corporation Stockholders' Equity		145,556	152,716
Noncontrolling interests		1,166	1,170
Total Equity		146,722	153,886
Total Liabilities and Equity		$ 260,078	$ 264,540
[1]	2015 adjusted to conform to ASU 2015-17. Refer to Note 18, "Income Taxes" beginning on page FS-45.
[2]	2015 adjusted to conform to ASU 2015-03. Refer to Note 5, "New Accounting Standards" beginning on page FS-32.
[3]	Refer to Note 25, "Other Contingencies and Commitments" beginning on page FS-61.

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Statement of Financial Position [Abstract]
Allowance for accounts and notes receivable, current	$ 373	$ 313
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	551,170,158	559,862,580
Unamortized discounts and debt issuance costs	$ 44	$ 43
Short-term Debt [Member]
Unamortized discounts and debt issuance costs	3	1
Long-term Debt [Member]
Unamortized discounts and debt issuance costs	$ 41	$ 42

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating Activities
Net Income (Loss)	$ (431)	$ 4,710	$ 19,310
Adjustments
Depreciation, depletion and amortization	19,457	21,037	16,793
Dry hole expense	489	2,309	875
Distributions less than income from equity affiliates	(1,227)	(760)	(2,202)
Net before-tax gains on asset retirements and sales	(1,149)	(3,215)	(3,540)
Net foreign currency effects	186	(82)	(277)
Deferred income tax provision	(3,835)	(1,861)	1,572
Net increase in operating working capital	(550)	(1,979)	(540)
(Increase) in long-term receivables	(131)	(59)	(9)
Decrease in other deferred charges	235	25	263
Cash contributions to employee pension plans	(870)	(868)	(392)
Other	672	199	(378)
Net Cash Provided by Operating Activities	12,846	19,456	31,475
Investing Activities
Capital expenditures	(18,109)	(29,504)	(35,407)
Proceeds and deposits related to asset sales	2,777	5,739	5,729
Net maturities of time deposits	0	8	0
Net sales (purchases) of marketable securities	297	122	(148)
Net (borrowing) repayment of loans by equity affiliates	(2,034)	(217)	140
Net sales (purchases) of other short-term investments	217	44	(207)
Net Cash Used for Investing Activities	(16,852)	(23,808)	(29,893)
Financing Activities
Net borrowings (repayments) of short-term obligations	2,130	(335)	3,431
Proceeds from issuances of long-term debt	6,924	11,091	4,000
Repayments of long-term debt and other financing obligations	(1,584)	(32)	(43)
Cash dividends - common stock	(8,032)	(7,992)	(7,928)
Distributions to noncontrolling interests	(63)	(128)	(47)
Net sales of treasury shares	650	211	(4,412)
Net Cash Provided by (Used for) Financing Activities	25	2,815	(4,999)
Effect of Exchange Rate Changes on Cash and Cash Equivalents	(53)	(226)	(43)
Net Change in Cash and Cash Equivalents	(4,034)	(1,763)	(3,460)
Cash and Cash Equivalents at January 1	11,022	12,785	16,245
Cash and Cash Equivalents at December 31	$ 6,988	$ 11,022	$ 12,785

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	Benefit Plan Trust (Common Stock)	Treasury Stock at Cost	Noncontrolling Interests
Balance at January 1, shares at Dec. 31, 2013														529,074
Balance at January 1 at Dec. 31, 2013					$ 15,713	$ 173,677		$ (23)	$ (6)	$ 52	$ (3,602)			$ (38,290)	$ 1,314
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Chevron Corporation	$ 19,241					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)
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)	$ (240)	$ (42,733)	1,163
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Chevron Corporation	4,587					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
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)	$ (240)	$ (42,493)	1,170
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) attributable to Chevron Corporation	(497)					(497)
Cash dividends on common stock						(8,032)
Stock dividends						(3)
Tax (charge) benefit from dividends paid on unallocated ESOP shares and other						0
Change during year	448							(22)	27	0	443
Purchases, shares														20
Purchases					265									$ (2)
Issuances - mainly employee benefit plans, shares														(8,713)
Issuances - mainly employee benefit plans														$ 661
Balance at December 31, shares at Dec. 31, 2016			0	2,442,677								14,168	14,168	551,170
Balance at December 31 at Dec. 31, 2016	$ 146,722	$ 145,556	$ 0	$ 1,832	$ 16,595	$ 173,046	$ (3,843)	$ (162)	$ (2)	$ (2)	$ (3,677)	$ (240)	$ (240)	$ (41,834)	$ 1,166

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2016
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 2 2 , beginning on page FS-54, 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 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 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 10 , beginning on page FS-37 , 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 2 6 , on page FS-62 , 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. Effective in the quarter ended December 31, 2016, the company has elected to move the annual review of the goodwill balance from the third to fourth quarter to better align with the preparation and review of the company's business plan, which is used in the test. The change does not delay, accelerate or avoid an impairment charge. 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 2 6 , on page FS-62 , 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-25 . 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 in the first, second and third anniversaries of the date of grant. Beginning in 2017, stock options and stock appreciation rights granted under the company’s Long-Term Incentive Plan have graded vesting by which one third of each award vests annually on each January 31 on or after the first anniversary of the grant date. Standard restricted stock units have cliff vesting by which the total award will vest on January 31 on or after the fifth anniversary of the grant date. The company amortizes these awards on a straight-line basis.

Changes in Accumulated Other Co

Changes in Accumulated Other Comprehensive Losses	12 Months Ended
	Dec. 31, 2016
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, 2016 , are reflected in the table below. Year Ended December 31, 2016 1 Currency Translation Adjustment Unrealized Holding Gains (Losses) on Securities Derivatives Defined Benefit Plans Total Balance at January 1 $ (140 ) $ (29 ) $ (2 ) $ (4,120 ) $ (4,291 ) Components of Other Comprehensive Income (Loss): Before Reclassifications (22 ) 27 — (161 ) (156 ) Reclassifications 2 — — — 604 604 Net Other Comprehensive Income (Loss) (22 ) 27 — 443 448 Balance at December 31 $ (162 ) $ (2 ) $ (2 ) $ (3,677 ) $ (3,843 ) 1 All amounts are net of tax. 2 Refer to Note 24 beginning on page FS-56, for reclassified components totaling $937 that are included in employee benefit costs for the year ending December 31, 2016 . Related income taxes for the same period, totaling $333 , 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, 2016
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 (Loss) Attributable to Chevron Corporation.” Activity for the equity attributable to noncontrolling interests for 2016 , 2015 and 2014 is as follows: 2016 2015 2014 Balance at January 1 $ 1,170 $ 1,163 $ 1,314 Net income 66 123 69 Distributions to noncontrolling interests (63 ) (128 ) (47 ) Other changes, net (7 ) 12 (173 ) Balance at December 31 $ 1,166 $ 1,170 $ 1,163

Information Relating to the Con

Information Relating to the Consolidated Statement of Cash Flows	12 Months Ended
	Dec. 31, 2016
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 2016 2015 2014 Net increase in operating working capital was composed of the following: (Increase) decrease in accounts and notes receivable $ (2,121 ) $ 3,631 $ 4,491 Decrease (increase) in inventories 603 85 (146 ) Decrease (increase) in prepaid expenses and other current assets 439 713 (407 ) Increase (decrease) in accounts payable and accrued liabilities 533 (5,769 ) (3,737 ) Decrease in income and other taxes payable (4 ) (639 ) (741 ) Net increase in operating working capital $ (550 ) $ (1,979 ) $ (540 ) Net cash provided by operating activities includes the following cash payments for interest on debt and for income taxes: Interest on debt (net of capitalized interest) $ 158 $ — $ — Income taxes 1,935 4,645 10,562 Net sales (purchases) of marketable securities consisted of the following gross amounts: Marketable securities purchased $ (9 ) $ (6 ) $ (162 ) Marketable securities sold 306 128 14 Net sales (purchases) of marketable securities $ 297 $ 122 $ (148 ) Net maturities of time deposits consisted of the following gross amounts: Investments in time deposits $ — $ — $ (317 ) Maturities of time deposits — 8 317 Net maturities of time deposits $ — $ 8 $ — Net (borrowing) repayment of loans by equity affiliates: Borrowing of loans by equity affiliates $ (2,341 ) $ (223 ) $ (176 ) Repayment of loans by equity affiliates 307 6 316 Net (borrowing) repayment of loans by equity affiliates $ (2,034 ) $ (217 ) $ 140 Net sales (purchases) of other short-term investments: Purchases of other short-term investments $ (1 ) $ (75 ) $ (223 ) Sales of other short-term investments 218 119 16 Net sales (purchases) of other short-term investments $ 217 $ 44 $ (207 ) Net borrowings (repayments) of short-term obligations consisted of the following gross and net amounts: Proceeds from issuances of short-term obligations $ 14,778 $ 13,805 $ 9,070 Repayments of short-term obligations (12,558 ) (16,379 ) (4,612 ) Net borrowings (repayments) of short-term obligations with three months or less maturity (90 ) 2,239 (1,027 ) Net borrowings (repayments) of short-term obligations $ 2,130 $ (335 ) $ 3,431 A loan to Tengizchevroil LLP for the development of the Future Growth and Wellhead Pressure Management Project represents the majority of " Net (borrowing) repayment of loans by equity affiliates ." The “ Net sales of treasury shares ” represents the cost of common shares acquired less the cost of shares issued for share-based compensation plans. Purchases totaled $2 , $2 and $5,006 in 2016 , 2015 and 2014 , respectively. No purchases were made under the company's share repurchase program in 2016 or 2015. In 2014 , the company purchased 41.5 million common shares for $5,000 under its share repurchase program. In 2016 , 2015 and 2014 , “ Net sales (purchases) of other short-term investments ” generally consisted of restricted cash associated with upstream abandonment activities, tax payments and certain pension fund payments 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" and "Deferred income tax provision" collectively include approximately $2,800 in non-cash reductions to properties, plant and equipment recorded in 2016 relating to impairments and other non-cash charges due to reservoir performance and lower crude prices. Refer also to Note 2 6 , on page FS-62 , 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, 2016 . 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 2016 2015 2014 Additions to properties, plant and equipment * $ 17,742 $ 28,213 $ 34,393 Additions to investments 55 555 526 Current-year dry hole expenditures 313 736 504 Payments for other liabilities and assets, net (1 ) — (16 ) Capital expenditures 18,109 29,504 35,407 Expensed exploration expenditures 544 1,031 1,110 Assets acquired through capital lease obligations and other financing obligations 5 47 332 Capital and exploratory expenditures, excluding equity affiliates 18,658 30,582 36,849 Company's share of expenditures by equity affiliates 3,770 3,397 3,467 Capital and exploratory expenditures, including equity affiliates $ 22,428 $ 33,979 $ 40,316 * Excludes noncash additions of $56 in 2016 , $1,362 in 2015 and $2,310 in 2014 .

New Accounting Standards

New Accounting Standards	12 Months Ended
	Dec. 31, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Standards	New Accounting Standards Revenue Recognition (Topic 606): Revenue from Contracts with Customers 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. 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 has elected to adopt the standard using the modified retrospective transition method. "Sales and Other Operating Revenues” on the Consolidated Statement of Income includes excise, value-added and similar taxes on sales transactions. Upon adoption of the standard, revenue will exclude sales-based taxes collected on behalf of third parties, which will have no impact to earnings. The company's implementation efforts are focused on accounting policy and disclosure updates and system enhancements necessary to meet the standard's requirements. The company continues to evaluate the effect of the standard on its consolidated financial statements. Interest - Imputation of Interest (Topic 835): Simplifying the Presentation of Debt Issuance Costs Effective January 1, 2016, Chevron adopted ASU 2015-03 on a retrospective basis. The standard requires that debt issuance costs related to a recognized liability be presented on the balance sheet as a direct deduction from the carrying amount of that debt liability. The effects of retrospective adoption on the December 31, 2015, Consolidated Balance Sheet were reductions of $43 in "Deferred charges and other assets," $1 in "Short-term debt" and $42 in "Long-term debt." Leases (Topic 842) In February 2016, the FASB issued ASU 2016-02 which becomes effective for the company January 1, 2019. The standard requires that lessees present right-of-use assets and lease liabilities on the balance sheet. The company is evaluating the effect of the standard on the company’s consolidated financial statements. Compensation-Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting In March 2016, the FASB issued ASU 2016-09 which the company elected to early-adopt retrospective to January 1, 2016. The standard requires that all excess tax benefits and tax deficiencies are recognized as income tax expense or benefit in the income statement, regardless of whether the benefit reduces taxes payable in the current period. In addition, excess tax benefits are to be classified along with other income tax cash flows as an operating activity in the statement of cash flows. The effect of the early adoption is not material to the company's consolidated financial statements. Financial Instruments - Credit Losses (Topic 326) In June 2016, the FASB issued ASU 2016-13, which becomes effective for the company beginning January 1, 2020. The standard requires companies to use forward-looking information to calculate credit loss estimates. The company is evaluating the effect of the standard on the company’s consolidated financial statements. Intangibles - Goodwill and Other (Topic 350) In January 2017, the FASB issued ASU 2017-04. The standard simplifies the accounting for goodwill impairment, and the company has chosen to early adopt beginning January 1, 2017. Early adoption has no effect on the company's consolidated financial statements.

Lease Commitments

Lease Commitments	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Lease Commitments	Lease Commitments Certain noncancellable 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 2016 2015 Upstream $ 676 $ 800 Downstream 99 98 All Other — — Total 775 898 Less: Accumulated amortization 383 448 Net capitalized leased assets $ 392 $ 450 Rental expenses incurred for operating leases during 2016 , 2015 and 2014 were as follows: Year ended December 31 2016 2015 2014 Minimum rentals $ 943 $ 1,041 $ 1,080 Contingent rentals 2 2 1 Total 945 1,043 1,081 Less: Sublease rental income 7 9 14 Net rental expense $ 938 $ 1,034 $ 1,067 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, 2016 , 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 2017 $ 615 $ 22 2018 554 20 2019 387 21 2020 298 12 2021 235 12 Thereafter 392 145 Total $ 2,481 $ 232 Less: Amounts representing interest and executory costs $ (125 ) Net present values 107 Less: Capital lease obligations included in short-term debt (14 ) Long-term capital lease obligations $ 93

Summarized Financial Data - Che

Summarized Financial Data - Chevron U.S.A. Inc.	12 Months Ended
	Dec. 31, 2016
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 2016 2015 2014 Sales and other operating revenues $ 83,715 $ 97,766 $ 157,198 Total costs and other deductions 87,429 101,565 153,139 Net income (loss) attributable to CUSA (1,177 ) (1,054 ) 3,849 2016 2015 * Current assets $ 11,266 $ 9,096 Other assets 55,722 59,171 Current liabilities 16,660 13,664 Other liabilities 21,701 28,465 Total CUSA net equity $ 28,627 $ 26,138 Memo: Total debt $ 9,418 $ 14,462 * 2015 adjusted to conform to ASU 2015-17 .

Summarized Financial Data - Ten

Summarized Financial Data - Tengizchevroil LLP	12 Months Ended
	Dec. 31, 2016
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 1 6 , beginning on page FS-43 , for a discussion of TCO operations. Summarized financial information for 100 percent of TCO is presented in the table below: Year ended December 31 2016 2015 2014 Sales and other operating revenues $ 10,460 $ 12,811 $ 22,813 Costs and other deductions 6,822 7,257 10,275 Net income attributable to TCO 2,563 3,897 8,772 At December 31 2016 2015 Current assets $ 7,001 $ 2,098 Other assets 20,476 17,094 Current liabilities 2,841 1,063 Other liabilities 6,210 2,266 Total TCO net equity $ 18,426 $ 15,863

Summarized Financial Data _ Che

Summarized Financial Data – Chevron Phillips Chemical Company LLC	12 Months Ended
	Dec. 31, 2016
Chevron Phillips Chemical Company LLC [Member]
Subsidiary Statements Captions [Line Items]
Summarized Financial Data – Chevron Phillips Chemical Company LLC	Summarized Financial Data – Chevron Phillips Chemical Company LLC Chevron has a 50 percent equity ownership interest in Chevron Phillips Chemical Company LLC (CPChem). Refer to Note 1 6 , beginning on page FS-43 , for a discussion of CPChem operations. Summarized financial information for 100 percent of CPChem is presented in the table below: Year ended December 31 2016 2015 2014 Sales and other operating revenues $ 8,455 $ 9,248 $ 13,416 Costs and other deductions 7,017 7,136 10,776 Net income attributable to CPChem 1,687 2,651 3,288 At December 31 2016 2015 Current assets $ 2,695 $ 2,291 Other assets 12,770 11,306 Current liabilities 1,418 1,319 Other liabilities 2,569 2,013 Total CPChem net equity $ 11,478 $ 10,265

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2016
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, 2016 , and December 31, 2015 . 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, 2016 . 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 2016 primarily due to reservoir performance and lower crude oil prices. The company reported impairments for certain oil and gas properties in 2015 primarily as a result of downward revisions in the company's longer-term crude oil price outlook. The impairments in 2016 and 2015 were primarily in Brazil and the United States. Investments and Advances The company did not have any material investments and advances measured at fair value on a nonrecurring basis to report in 2016 or 2015 . Assets and Liabilities Measured at Fair Value on a Recurring Basis At Dec ember 31, 2016 At December 31, 2015 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Marketable securities $ 13 $ 13 $ — $ — $ 310 $ 310 $ — $ — Derivatives 32 15 17 — 205 189 16 — Total assets at fair value $ 45 $ 28 $ 17 $ — $ 515 $ 499 $ 16 $ — Derivatives 109 78 31 — 53 47 6 — Total liabilities at fair value $ 109 $ 78 $ 31 $ — $ 53 $ 47 $ 6 $ — 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 2016 Total Level 1 Level 2 Level 3 Year 2015 Properties, plant and equipment, net (held and used) $ 582 $ — $ 15 $ 567 $ 2,507 $ 3,051 $ — $ 239 $ 2,812 $ 3,222 Properties, plant and equipment, net (held for sale) 891 — 888 3 679 937 — 937 — 844 Investments and advances 26 — 20 6 234 75 — 75 — 28 Total nonrecurring assets at fair value $ 1,499 $ — $ 923 $ 576 $ 3,420 $ 4,063 $ — $ 1,251 $ 2,812 $ 4,094 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 $6,988 and $11,022 at December 31, 2016 , and December 31, 2015 , respectively. The fair values of cash and cash equivalents are classified as Level 1 and reflect the cash that would have been received if the instruments were settled at December 31, 2016 . "Cash and cash equivalents” do not include investments with a carrying/fair value of $1,426 and $1,100 at December 31, 2016 , and December 31, 2015 , respectively. At December 31, 2016 , these investments are classified as Level 1 and include restricted funds related to certain upstream abandonment activities, tax payments, funds held in escrow for tax-deferred exchanges and refundable deposits related to pending asset sales, which are reported in “Deferred charges and other assets” on the Consolidated Balance Sheet. Long-term debt of $26,193 and $25,542 at December 31, 2016 , and December 31, 2015 , had estimated fair values of $26,627 and $25,884 , respectively. Long-term debt primarily includes corporate issued bonds. The fair value of corporate bonds is $25,860 and classified as Level 1. The fair value of other long-term debt 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, 2016 and 2015 , were not material.

Financial and Derivative Instru

Financial and Derivative Instruments	12 Months Ended
	Dec. 31, 2016
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, 2016 , December 31, 2015 , and December 31, 2014 , and their classification on the Consolidated Balance Sheet and Consolidated Statement of Income are below: Consolidated Balance Sheet: Fair Value of Derivatives Not Designated as Hedging Instruments At December 31 Type of Contract Balance Sheet Classification 2016 2015 Commodity Accounts and notes receivable, net $ 30 $ 200 Commodity Long-term receivables, net 2 5 Total assets at fair value $ 32 $ 205 Commodity Accounts payable $ 99 $ 51 Commodity Deferred credits and other noncurrent obligations 10 2 Total liabilities at fair value $ 109 $ 53 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 2016 2015 2014 Commodity Sales and other operating revenues $ (269 ) $ 277 $ 553 Commodity Purchased crude oil and products (31 ) 30 (17 ) Commodity Other income — (3 ) (32 ) $ (300 ) $ 304 $ 504 The table on the following page represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at December 31, 2016 and December 31, 2015 . 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, 2016 Derivative Assets $ 1,052 $ 1,020 $ 32 $ — $ 32 Derivative Liabilities $ 1,129 $ 1,020 $ 109 $ — $ 109 At December 31, 2015 Derivative Assets $ 2,459 $ 2,254 $ 205 $ — $ 205 Derivative Liabilities $ 2,307 $ 2,254 $ 53 $ — $ 53 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, 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, 2016
Assets Held For Sale [Abstract]
Assets Held For Sale	Assets Held for Sale At December 31, 2016 , the company classified $4,119 of net properties, plant and equipment as “Assets held for sale” on the Consolidated Balance Sheet. These assets are associated with upstream operations that are anticipated to be sold in the next 12 months. The revenues and earnings contributions of these assets in 2016 were not material.

Equity

Equity	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Equity	Equity Retained earnings at December 31, 2016 and 2015 , included approximately $16,479 and $15,010 , respectively, for the company’s share of undistributed earnings of equity affiliates. At December 31, 2016 , about 87 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, 859,746 shares remain available for issuance from the 1,600,000 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, 2016
Earnings Per Share [Abstract]
Earnings Per Share	Earnings Per Share Basic earnings per share (EPS) is based upon “Net Income (Loss) 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 2 3 , “Stock Options and Other Share-Based Compensation,” beginning on page FS-55 ). The table on the following page sets forth the computation of basic and diluted EPS: Year ended December 31 2016 2015 2014 Basic EPS Calculation Earnings available to common stockholders - Basic 1 $ (497 ) $ 4,587 $ 19,241 Weighted-average number of common shares outstanding 2 1,872 1,867 1,883 Add: Deferred awards held as stock units 1 1 1 Total weighted-average number of common shares outstanding 1,873 1,868 1,884 Earnings per share of common stock - Basic $ (0.27 ) $ 2.46 $ 10.21 Diluted EPS Calculation Earnings available to common stockholders - Diluted 1 $ (497 ) $ 4,587 $ 19,241 Weighted-average number of common shares outstanding 2 1,872 1,867 1,883 Add: Deferred awards held as stock units 1 1 1 Add: Dilutive effect of employee stock-based awards — 7 14 Total weighted-average number of common shares outstanding 1,873 1,875 1,898 Earnings per share of common stock - Diluted $ (0.27 ) $ 2.45 $ 10.14 1 There was no effect of dividend equivalents paid on stock units or dilutive impact of employee stock-based awards on earnings. 2 Millions of shares; 10 million shares of employee-based awards were not included in the 2016 diluted EPS calculation as the result would be anti-dilutive.

Operating Segments and Geograph

Operating Segments and Geographic Data	12 Months Ended
	Dec. 31, 2016
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 table on the following page: Year ended December 31 2016 2015 2014 Upstream United States $ (2,054 ) $ (4,055 ) $ 3,327 International (483 ) 2,094 13,566 Total Upstream (2,537 ) (1,961 ) 16,893 Downstream United States 1,307 3,182 2,637 International 2,128 4,419 1,699 Total Downstream 3,435 7,601 4,336 Total Segment Earnings 898 5,640 21,229 All Other Interest expense (168 ) — — Interest income 58 65 77 Other (1,285 ) (1,118 ) (2,065 ) Net Income (Loss) Attributable to Chevron Corporation $ (497 ) $ 4,587 $ 19,241 Segment Assets Segment assets do not include intercompany investments or receivables. Assets at year-end 2016 and 2015 are as follows: At December 31 2016 2015 Upstream United States 1 $ 42,596 $ 46,383 International 1 164,068 162,030 Goodwill 4,581 4,588 Total Upstream 211,245 213,001 Downstream United States 1 22,264 21,404 International 15,816 14,982 Total Downstream 38,080 36,386 Total Segment Assets 249,325 249,387 All Other United States 1,2 4,852 4,728 International 5,901 10,425 Total All Other 10,753 15,153 Total Assets – United States 1,2 69,712 72,515 Total Assets – International 1 185,785 187,437 Goodwill 4,581 4,588 Total Assets $ 260,078 $ 264,540 1 2015 adjusted to conform to ASU 2015-17. Refer to Note 1 9 , "Income Taxes" beginning on page FS-49 . 2 2015 adjusted to conform to ASU 2015-03. Refer to Note 5 , "New Accounting Standards" on page FS-34 . Segment Sales and Other Operating Revenues Operating segment sales and other operating revenues, including internal transfers, for the years 2016 , 2015 and 2014 , 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 2016 2015 2014 Upstream United States $ 3,148 $ 4,117 $ 7,455 Intersegment 7,217 8,631 15,455 Total United States 10,365 12,748 22,910 International 13,262 15,587 23,808 Intersegment 9,518 11,492 23,107 Total International 22,780 27,079 46,915 Total Upstream 33,145 39,827 69,825 Downstream United States 40,366 48,420 73,942 Excise and similar taxes 4,335 4,426 4,633 Intersegment 16 26 31 Total United States 44,717 52,872 78,606 International 46,388 54,296 86,848 Excise and similar taxes 2,570 2,933 3,553 Intersegment 1,068 1,528 8,839 Total International 50,026 58,757 99,240 Total Downstream 94,743 111,629 177,846 All Other United States 145 141 252 Intersegment 960 1,372 1,475 Total United States 1,105 1,513 1,727 International 1 5 3 Intersegment 36 37 28 Total International 37 42 31 Total All Other 1,142 1,555 1,758 Segment Sales and Other Operating Revenues United States 56,187 67,133 103,243 International 72,843 85,878 146,186 Total Segment Sales and Other Operating Revenues 129,030 153,011 249,429 Elimination of intersegment sales (18,815 ) (23,086 ) (48,935 ) Total Sales and Other Operating Revenues $ 110,215 $ 129,925 $ 200,494 Segment Income Taxes Segment income tax expense for the years 2016 , 2015 and 2014 is as follows: Year ended December 31 2016 2015 2014 Upstream United States $ (1,172 ) $ (2,041 ) $ 2,043 International 166 1,214 9,217 Total Upstream (1,006 ) (827 ) 11,260 Downstream United States 503 1,320 1,302 International 484 1,313 467 Total Downstream 987 2,633 1,769 All Other (1,710 ) (1,674 ) (1,137 ) Total Income Tax Expense (Benefit) $ (1,729 ) $ 132 $ 11,892 Other Segment Information Additional information for the segmentation of major equity affiliates is contained in Note 1 6 , on page FS-43 . Information related to properties, plant and equipment by segment is contained in Note 1 7 , on page FS-44 .

Investments and Advances

Investments and Advances	12 Months Ended
	Dec. 31, 2016
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 2016 2015 2016 2015 2014 Upstream Tengizchevroil $ 11,414 $ 8,077 $ 1,380 $ 1,939 $ 4,392 Petropiar 977 679 326 180 26 Caspian Pipeline Consortium 1,245 1,342 145 162 191 Petroboscan 982 1,163 (133 ) 219 186 Angola LNG Limited 2,744 3,284 (282 ) (417 ) (311 ) Other 1,791 2,158 (193 ) 135 229 Total Upstream 19,153 16,703 1,243 2,218 4,713 Downstream GS Caltex Corporation 3,767 3,620 373 824 420 Chevron Phillips Chemical Company LLC 5,767 5,196 840 1,367 1,606 Caltex Australia Ltd. — — — 92 183 Other 1,118 1,077 209 186 180 Total Downstream 10,652 9,893 1,422 2,469 2,389 All Other Other (16 ) (18 ) (4 ) (3 ) (4 ) Total equity method $ 29,789 $ 26,578 $ 2,661 $ 4,684 $ 7,098 Other at or below cost 461 532 Total investments and advances $ 30,250 $ 27,110 Total United States $ 7,258 $ 6,863 $ 802 $ 1,342 $ 1,623 Total International $ 22,992 $ 20,247 $ 1,859 $ 3,342 $ 5,475 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, 2016 , the company’s carrying value of its investment in TCO was about $140 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. In July 2016, the company made a $2,000 long-term loan to TCO to fund the development of the Future Growth and Wellhead Pressure Management Project. See Note 8 , on page FS-36 , 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, 2016 , the company’s carrying value of its investment in Petropiar was approximately $150 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 $1,245 , which includes long-term loans of $921 at year-end 2016 . 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, 2016 , the company’s carrying value of its investment in Petroboscan was approximately $120 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. The company also has an outstanding long-term loan to Petroboscan of $626 at year-end 2016. 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. Other Information “Sales and other operating revenues” on the Consolidated Statement of Income includes $5,786 , $4,850 and $10,404 with affiliated companies for 2016 , 2015 and 2014 , respectively. “Purchased crude oil and products” includes $3,468 , $4,240 and $6,735 with affiliated companies for 2016 , 2015 and 2014 , respectively. “Accounts and notes receivable” on the Consolidated Balance Sheet includes $676 and $399 due from affiliated companies at December 31, 2016 and 2015 , respectively. “Accounts payable” includes $383 and $286 due to affiliated companies at December 31, 2016 and 2015 , 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 $3,535 , $410 and $874 at December 31, 2016 , 2015 and 2014 , respectively. Affiliates Chevron Share Year ended December 31 2016 2015 2014 2016 2015 2014 Total revenues $ 59,253 $ 71,389 $ 123,003 $ 27,787 $ 33,492 $ 58,937 Income before income tax expense 6,587 13,129 20,609 3,670 6,279 9,968 Net income attributable to affiliates 5,127 10,649 14,758 2,876 4,691 7,237 At December 31 Current assets $ 33,406 $ 27,162 $ 35,662 $ 13,743 $ 10,657 $ 13,465 Noncurrent assets 75,258 71,650 70,817 28,854 26,607 26,053 Current liabilities 24,793 20,559 25,308 8,996 7,351 9,588 Noncurrent liabilities 22,671 18,560 17,983 4,255 3,909 4,211 Total affiliates' net equity $ 61,200 $ 59,693 $ 63,188 $ 29,346 $ 26,004 $ 25,719

Properties, Plant and Equipment

Properties, Plant and Equipment	12 Months Ended
	Dec. 31, 2016
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 2016 2015 2014 2016 2015 2014 2016 2015 2014 2016 2015 2014 Upstream United States $ 83,929 $ 93,848 $ 96,850 $ 39,710 $ 43,125 $ 45,864 $ 4,432 $ 6,586 $ 9,688 $ 6,576 $ 8,545 $ 5,127 International 214,557 208,395 192,637 125,502 127,459 118,926 12,084 19,993 24,920 11,247 10,803 9,688 Total Upstream 298,486 302,243 289,487 165,212 170,584 164,790 16,516 26,579 34,608 17,823 19,348 14,815 Downstream United States 22,795 23,202 22,640 10,196 10,807 11,019 528 696 588 956 878 886 International 9,350 9,177 9,334 4,094 4,090 4,219 375 365 530 332 355 396 Total Downstream 32,145 32,379 31,974 14,290 14,897 15,238 903 1,061 1,118 1,288 1,233 1,282 All Other United States 5,263 5,500 5,673 2,635 2,859 3,077 198 357 581 328 439 680 International 183 155 155 49 56 68 6 5 25 18 17 16 Total All Other 5,446 5,655 5,828 2,684 2,915 3,145 204 362 606 346 456 696 Total United States 111,987 122,550 125,163 52,541 56,791 59,960 5,158 7,639 10,857 7,860 9,862 6,693 Total International 224,090 217,727 202,126 129,645 131,605 123,213 12,465 20,363 25,475 11,597 11,175 10,100 Total $ 336,077 $ 340,277 $ 327,289 $ 182,186 $ 188,396 $ 183,173 $ 17,623 $ 28,002 $ 36,332 $ 19,457 $ 21,037 $ 16,793 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 2016 . Australia had PP&E of $53,962 , $49,205 and $41,012 in 2016 , 2015 , and 2014 , respectively. Nigeria had PP&E of $17,922 , $18,773 and $19,214 for 2016 , 2015 and 2014 , respectively. 2 Net of dry hole expense related to prior years’ expenditures of $175 , $1,573 and $371 in 2016 , 2015 and 2014 , respectively. 3 Depreciation expense includes accretion expense of $749 , $715 and $882 in 2016 , 2015 and 2014 , respectively, and impairments of $3,186 , $4,066 and $1,274 in 2016 , 2015 and 2014 , respectively.

Litigation

Litigation	12 Months Ended
	Dec. 31, 2016
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 six 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 28, 2015, the Court of Appeals denied the Government of Ecuador's request for full appellate court review of the Federal District Court's decision. On June 6, 2016, the United States Supreme Court denied the Government of Ecuador's petition for Writ of Certiorari. On July 22, 2016, the Government of Ecuador paid the $96 award, plus interest, resulting in a payment to Chevron of approximately $113 . 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 January 20, 2017, the Ontario Superior Court of Justice granted Chevron Canada Limited’s and Chevron Corporation’s motions for summary judgment, concluding that the two companies are separate legal entities with separate rights and obligations. As a result, the Superior Court dismissed the recognition and enforcement claim against Chevron Canada Limited. Chevron Corporation still remains as a defendant in the action. On February 3, 2017, the Lago Agrio plaintiffs appealed the Superior Court's January 20, 2017 decision. 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. On April 19, 2016, the public prosecutor in Argentina issued a non-binding opinion recommending to the National Court, First Instance, of Argentina that it reject the Lago Agrio plaintiffs' request to recognize the Ecuadorian judgment in Argentina. 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. On April 13, 2016, the Republic of Ecuador appealed the decision. 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. On August 8, 2016, the Second Circuit issued a unanimous opinion affirming in full the judgment of the Federal District Court in favor of Chevron. On October 27, 2016, the Second Circuit denied the defendants' petitions for en banc rehearing of the opinion on their appeal. 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, 2016
Income Tax Disclosure [Abstract]
Taxes	Taxes Income Taxes Year ended December 31 2016 2015 2014 Income tax expense (benefit) U.S. federal Current $ (623 ) $ (817 ) $ 748 Deferred (1,558 ) (580 ) 1,330 State and local Current (15 ) (187 ) 336 Deferred (121 ) (109 ) 36 Total United States (2,317 ) (1,693 ) 2,450 International Current 2,744 2,997 9,235 Deferred (2,156 ) (1,172 ) 207 Total International 588 1,825 9,442 Total income tax expense (benefit) $ (1,729 ) $ 132 $ 11,892 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: 2016 2015 1 2014 1 Income (loss) before income taxes United States $ (4,317 ) $ (2,877 ) $ 6,296 International 2,157 7,719 24,906 Total income (loss) before income taxes (2,160 ) 4,842 31,202 Theoretical tax (at U.S. statutory rate of 35%) (756 ) 1,695 10,921 Equity affiliate accounting effect (704 ) (1,286 ) (2,039 ) Effect of income taxes from international operations 608 72 2,708 State and local taxes on income, net of U.S. federal income tax benefit (44 ) (74 ) 234 Prior year tax adjustments, claims and settlements (349 ) 84 (76 ) Tax credits (188 ) (35 ) (68 ) Other 2 (296 ) (324 ) 212 Total income tax expense (benefit) $ (1,729 ) $ 132 $ 11,892 Effective income tax rate 80.0 % 2.7 % 38.1 % 1 2014 and 2015 conformed to 2016 presentation. 2 Includes one-time tax benefits associated with changes in uncertain tax positions and valuation allowances. The 2016 decline in income tax expense of $1,861 , from an expense of $132 in 2015 to a benefit of $1,729 in 2016, is a result of the year-over-year reduction in total income before income tax expense, which is primarily due to effects of lower crude oil prices. The company’s effective tax rate changed from 2.7 percent in 2015 to 80 percent in 2016 . The change in effective tax rate is primarily a consequence of the mix effect resulting from the absolute level of earnings or losses and whether they arose in higher or lower tax rate jurisdictions. The company records its deferred taxes on a tax-jurisdiction basis. The reported deferred tax balances are composed of the following: At December 31 2016 2015 Deferred tax liabilities Properties, plant and equipment $ 25,180 $ 27,044 Investments and other 5,222 3,743 Total deferred tax liabilities 30,402 30,787 Deferred tax assets Foreign tax credits (10,976 ) (10,534 ) Abandonment/environmental reserves (6,251 ) (6,880 ) Employee benefits (4,392 ) (4,801 ) Deferred credits (1,950 ) (1,810 ) Tax loss carryforwards (6,030 ) (2,748 ) Other accrued liabilities (510 ) (525 ) Inventory (374 ) (120 ) Miscellaneous (3,121 ) (2,525 ) Total deferred tax assets (33,604 ) (29,943 ) Deferred tax assets valuation allowance 16,069 15,412 Total deferred taxes, net $ 12,867 $ 16,256 Deferred tax liabilities at the end of 2016 were essentially unchanged from year-end 2015 . Deferred tax assets increased by approximately $3,700 in 2016. The increase primarily related to increased 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 2016 , the company had tax loss carryforwards of approximately $16,538 and tax credit carryforwards of approximately $1,423 , 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 2017 through 2036 . U.S. foreign tax credit carryforwards of $10,976 will expire between 2017 and 2026 . At December 31, 2016 and 2015 , deferred taxes were classified on the Consolidated Balance Sheet as follows: At December 31 2016 2015 Deferred charges and other assets $ (4,649 ) $ (3,909 ) Noncurrent deferred income taxes 17,516 20,165 Total deferred income taxes, net $ 12,867 $ 16,256 Effective January 1, 2016, Chevron early-adopted Income Taxes (Topic 740), Balance Sheet Classification of Deferred Taxes (ASU 2015-17) , on a retrospective basis. The standard provides that all deferred income taxes be classified as noncurrent on the Consolidated Balance Sheet. The prior requirement was to classify most deferred tax assets and liabilities based on the classification of the underlying asset or liability. The December 31, 2015, Consolidated Balance Sheet has been restated and the effects are reductions of $917 in "Prepaid expenses and other current assets," $603 in "Deferred charges and other assets," $996 in "Federal and other taxes on income," and $524 in "Noncurrent deferred income taxes." 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 $46,400 at December 31, 2016 . 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 2016 , 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, 2016 , 2015 and 2014 . 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. 2016 2015 2014 Balance at January 1 $ 3,042 $ 3,552 $ 3,848 Foreign currency effects 1 (27 ) (25 ) Additions based on tax positions taken in current year 245 154 354 Additions/reductions resulting from current-year asset acquisitions/sales — — (22 ) Additions for tax positions taken in prior years 181 218 37 Reductions for tax positions taken in prior years (390 ) (678 ) (561 ) Settlements with taxing authorities in current year (36 ) (5 ) (50 ) Reductions as a result of a lapse of the applicable statute of limitations (12 ) (172 ) (29 ) Balance at December 31 $ 3,031 $ 3,042 $ 3,552 Approximately 74 percent of the $3,031 of unrecognized tax benefits at December 31, 2016 , 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, 2016 . For these jurisdictions, the latest years for which income tax examinations had been finalized were as follows: United States – 2011 , Nigeria – 2000 , Angola – 2009 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, 2016 , accruals of $424 for anticipated interest and penalty obligations were included on the Consolidated Balance Sheet, compared with accruals of $399 as of year-end 2015 . Income tax expense associated with interest and penalties was $38 , $195 and $4 in 2016 , 2015 and 2014 , respectively. Taxes Other Than on Income Year ended December 31 2016 2015 2014 United States Excise and similar taxes on products and merchandise $ 4,335 $ 4,426 $ 4,633 Import duties and other levies 9 4 6 Property and other miscellaneous taxes 1,680 1,367 1,002 Payroll taxes 252 270 273 Taxes on production 159 157 349 Total United States 6,435 6,224 6,263 International Excise and similar taxes on products and merchandise 2,570 2,933 3,553 Import duties and other levies 33 40 45 Property and other miscellaneous taxes 2,379 2,548 2,277 Payroll taxes 145 161 172 Taxes on production 106 124 230 Total International 5,233 5,806 6,277 Total taxes other than on income $ 11,668 $ 12,030 $ 12,540

Short-Term Debt

Short-Term Debt	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Short-Term Debt	Short-Term Debt At December 31 2016 2015 Commercial paper 1 $ 10,410 $ 8,252 Notes payable to banks and others with originating terms of one year or less 50 20 Current maturities of long-term debt 2 6,253 1,486 Current maturities of long-term capital leases 14 17 Redeemable long-term obligations Long-term debt 3,113 3,152 Capital leases — — Subtotal 19,840 12,927 Reclassified to long-term debt (9,000 ) (8,000 ) Total short-term debt $ 10,840 $ 4,927 1 Weighted-average interest rates at December 31, 2016 and 2015, were 0.74 percent and 0.26 percent, respectively. 2 2015 adjusted to conform to ASU 2015-03. Refer to Note 5, "New Accounting Standards" on page FS-34. 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, 2016 , the company had no interest rate swaps on short-term debt. At December 31, 2016 , the company had $9,000 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 $6,900 or the company can convert any amounts outstanding into a term loan for a period of up to one year, and a $2,100 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, 2016 . The company classified $9,000 and $8,000 of short-term debt as long-term at December 31, 2016 and 2015 , respectively. 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, 2016
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Total long-term debt, excluding capital leases, at December 31, 2016 , was $35,193 . The company’s long-term debt outstanding at year-end 2016 and 2015 was as follows: At December 31 2016 2015 Principal Unamortized discounts and debt issuance costs Principal Unamortized discounts and debt issuance costs 3.191% notes due 2023 $ 2,250 $ 4 $ 2,250 $ 4 2.954% notes due 2026 2,250 6 — — Floating rate notes due 2017 (1.091%) 1 2,050 1 2,050 2 1.104% notes due 2017 2,000 1 2,000 2 1.718% notes due 2018 2,000 1 2,000 2 2.355% notes due 2022 2,000 5 2,000 5 1.365% notes due 2018 1,750 1 1,750 2 1.961% notes due 2020 1,750 2 1,750 2 Floating rate notes due 2018 (1.310%) 1 1,650 2 800 1 4.95% notes due 2019 1,500 2 1,500 2 1.561% notes due 2019 1,350 2 — — 2.100% notes due 2021 1,350 2 — — 1.790% notes due 2018 1,250 1 1,250 2 2.419% notes due 2020 1,250 2 1,250 2 1.345% notes due 2017 1,100 — 1,100 2 1.344% notes due 2017 1,000 1 1,000 1 2.427% notes due 2020 1,000 1 1,000 2 2.193% notes due 2019 750 1 750 1 2.566% notes due 2023 750 1 — — 3.326% notes due 2025 750 2 750 2 2.411% notes due 2022 700 1 700 1 Floating rate notes due 2021 (1.599%) 1 650 1 400 1 Floating rate notes due 2019 (1.316%) 2 400 1 400 2 Floating rate notes due 2022 (1.472%) 2 350 — 350 1 Amortizing bank loan due 2018 (1.527%) 1 178 — 110 — 8.625% debentures due 2032 147 1 147 1 8.625% debentures due 2031 108 1 108 1 8% debentures due 2032 75 1 74 1 9.75% debentures due 2020 54 — 54 — 8.875% debentures due 2021 40 — 40 — Medium-term notes, maturing from 2021 to 2038 (6.133%) 1 38 — 38 — 0.889% notes due 2016 — — 750 — Floating rate notes due 2016 — — 700 1 Total including debt due within one year 32,490 44 27,071 43 Debt due within one year (6,256 ) (3 ) (1,487 ) (1 ) Reclassified from short-term debt 9,000 8,000 Total long-term debt $ 35,234 $ 41 $ 33,584 $ 42 1 Weighted-average interest rate at December 31, 2016 . 2 Interest rate at December 31, 2016. 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 with a principal balance of $32,490 matures as follows: 2017 – $6,256 ; 2018 – $6,722 ; 2019 – $4,000 ; 2020 – $4,054 ; 2021 – $2,054 ; and after 2021 – $9,404 . The company completed a bond issuance of $6,800 in May 2016. Effective January 1, 2016, Chevron adopted ASU 2015-03 on a retrospective basis. The standard requires that debt issuance costs related to a recognized liability be presented on the balance sheet as a direct deduction from the carrying amount of that debt liability. On the Consolidated Balance Sheet, long-term debt net of unamortized discounts and debt issuance costs was $35,193 at December 31, 2016 , and $33,542 at December 31, 2015 . See Note 10 , beginning on page FS-37 , 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, 2016
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, 2016 : 2016 2015 2014 Beginning balance at January 1 $ 3,312 $ 4,195 $ 3,245 Additions to capitalized exploratory well costs pending the determination of proved reserves 465 869 1,591 Reclassifications to wells, facilities and equipment based on the determination of proved reserves (119 ) (164 ) (298 ) Capitalized exploratory well costs charged to expense (118 ) (1,397 ) (312 ) Other reductions * — (191 ) (31 ) Ending balance at December 31 $ 3,540 $ 3,312 $ 4,195 * 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 2016 2015 2014 Exploratory well costs capitalized for a period of one year or less $ 445 $ 489 $ 1,522 Exploratory well costs capitalized for a period greater than one year 3,095 2,823 2,673 Balance at December 31 $ 3,540 $ 3,312 $ 4,195 Number of projects with exploratory well costs that have been capitalized for a period greater than one year * 35 39 51 * Certain projects have multiple wells or fields or both. Of the $3,095 of exploratory well costs capitalized for more than one year at December 31, 2016 , $1,939 ( 15 projects) is related to projects that had drilling activities underway or firmly planned for the near future. The $1,156 balance is related to 20 projects in areas requiring a major capital expenditure before production could begin and for which additional drilling efforts were not underway 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 $1,156 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) $107 ( two projects) – development concept under review by government; (c) $816 ( seven projects) – development alternatives under review; (d) $43 ( nine projects) – miscellaneous activities for projects with smaller amounts suspended. While progress was being made on all 35 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. More than half of these decisions are expected to occur in the next five years . The $3,095 of suspended well costs capitalized for a period greater than one year as of December 31, 2016 , represents 160 exploratory wells in 35 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 1998-2005 $ 311 29 2006-2010 684 40 2011-2015 2,100 91 Total $ 3,095 160 Aging based on drilling completion date of last suspended well in project: Amount Number of projects 2003-2008 $ 212 4 2009-2012 437 8 2013-2016 2,446 23 Total $ 3,095 35

Stock Options and Other Share-B

Stock Options and Other Share-Based Compensation	12 Months Ended
	Dec. 31, 2016
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 2016 , 2015 and 2014 was $271 ( $176 after tax), $312 ( $203 after tax) and $287 ( $186 after tax), respectively. In addition, compensation expense for stock appreciation rights, restricted stock, performance shares and restricted stock units was $371 ( $241 after tax), $32 ( $21 after tax) and $71 ( $46 after tax) for 2016 , 2015 and 2014 , respectively. No significant stock-based compensation cost was capitalized at December 31, 2016 , or December 31, 2015 . Cash received in payment for option exercises under all share-based payment arrangements for 2016 , 2015 and 2014 was $647 , $195 and $527 , respectively. Actual tax benefits realized for the tax deductions from option exercises were $21 , $17 and $54 for 2016 , 2015 and 2014 , respectively. Cash paid to settle performance shares and stock appreciation rights was $82 , $104 and $204 for 2016 , 2015 and 2014 , 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 shares 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, 2016 , the contractual terms vary between three years for the performance shares and restricted stock units, and 10 years for the stock options and stock appreciation rights. For awards that will be issued in 2017, contractual terms vary between three years for the performance shares and special restricted stock units, 5 years for standard restricted stock units and 10 years for the stock options and stock appreciation rights. Forfeitures for performance shares, restricted stock units, and stock appreciation rights are recognized as they occur. Forfeitures for stock options are estimated using historical forfeiture data dating back to 1990. The fair market values of stock options and stock appreciation rights granted in 2016 , 2015 and 2014 were measured on the date of grant using the Black-Scholes option-pricing model, with the following weighted-average assumptions: Year ended December 31 2016 2015 2014 Expected term in years 1 6.3 6.1 6.0 Volatility 2 21.7 % 21.9 % 30.3 % Risk-free interest rate based on zero coupon U.S. treasury note 1.6 % 1.4 % 1.9 % Dividend yield 4.5 % 3.6 % 3.3 % Weighted-average fair value per option granted $ 9.53 $ 13.89 $ 25.86 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 2016 is presented below: Shares (Thousands) Weighted-Average Exercise Price Averaged Remaining Contractual Term (Years) Aggregate Intrinsic Value Outstanding at January 1, 2016 94,292 $ 96.67 Granted 30,913 $ 83.31 Exercised (8,589 ) $ 75.57 Forfeited (4,341 ) $ 86.81 Outstanding at December 31, 2016 112,275 $ 94.99 6.13 $ 2,550 Exercisable at December 31, 2016 71,153 $ 97.32 4.66 $ 1,450 The total intrinsic value (i.e., the difference between the exercise price and the market price) of options exercised during 2016 , 2015 and 2014 was $240 , $120 and $398 , respectively. During this period, the company continued its practice of issuing treasury shares upon exercise of these awards. As of December 31, 2016 , there was $169 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, 2016 , the number of LTIP performance units outstanding was equivalent to 2,192,937 shares. During 2016 , 1,019,900 units were granted, 718,472 units vested with cash proceeds distributed to recipients and 100,937 units were forfeited. At December 31, 2016 , units outstanding were 2,393,428 . The fair value of the liability recorded for these instruments was $381 , 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 5.4 million equivalent shares as of December 31, 2016 . A liability of $125 was recorded for these awards.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2016
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. Beginning in 2017, medical coverage for Medicare-eligible retirees in the company’s main U.S. medical plan is provided through a third-party private exchange. The increase to the pre-Medicare 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 2016 and 2015 follows: Pension Benefits 2016 2015 Other Benefits U.S. Int’l. U.S. Int’l. 2016 2015 Change in Benefit Obligation Benefit obligation at January 1 $ 13,563 $ 5,336 $ 14,250 $ 5,767 $ 3,324 $ 3,660 Service cost 494 159 538 185 60 72 Interest cost 377 261 502 277 128 151 Plan participants' contributions — 5 — 6 148 148 Plan amendments — — — (6 ) (345 ) — Actuarial (gain) loss 903 426 (345 ) (309 ) (437 ) (326 ) Foreign currency exchange rate changes — (524 ) — (326 ) 8 (37 ) Benefits paid (2,066 ) (494 ) (1,382 ) (241 ) (337 ) (344 ) Curtailment — — — (17 ) — — Benefit obligation at December 31 13,271 5,169 13,563 5,336 2,549 3,324 Change in Plan Assets Fair value of plan assets at January 1 10,274 4,109 11,090 4,244 — — Actual return on plan assets 936 642 (75 ) 112 — — Foreign currency exchange rate changes — (552 ) — (239 ) — — Employer contributions 406 464 641 227 189 196 Plan participants' contributions — 5 — 6 148 148 Benefits paid (2,066 ) (494 ) (1,382 ) (241 ) (337 ) (344 ) Fair value of plan assets at December 31 9,550 4,174 10,274 4,109 — — Funded status at December 31 $ (3,721 ) $ (995 ) $ (3,289 ) $ (1,227 ) $ (2,549 ) $ (3,324 ) Amounts recognized on the Consolidated Balance Sheet for the company’s pension and OPEB plans at December 31, 2016 and 2015 , include: Pension Benefits 2016 2015 Other Benefits U.S. Int’l. U.S. Int’l. 2016 2015 Deferred charges and other assets $ 16 $ 199 $ 13 $ 333 $ — $ — Accrued liabilities (222 ) (75 ) (153 ) (77 ) (163 ) (191 ) Noncurrent employee benefit plans (3,515 ) (1,119 ) (3,149 ) (1,483 ) (2,386 ) (3,133 ) Net amount recognized at December 31 $ (3,721 ) $ (995 ) $ (3,289 ) $ (1,227 ) $ (2,549 ) $ (3,324 ) Amounts recognized on a before-tax basis in “Accumulated other comprehensive loss” for the company’s pension and OPEB plans were $5,511 and $6,478 at the end of 2016 and 2015 , respectively. These amounts consisted of: Pension Benefits 2016 2015 Other Benefits U.S. Int’l. U.S. Int’l. 2016 2015 Net actuarial loss $ 4,653 $ 1,145 $ 4,809 $ 1,143 $ (82 ) $ 367 Prior service (credit) costs 4 106 (5 ) 120 (315 ) 44 Total recognized at December 31 $ 4,657 $ 1,251 $ 4,804 $ 1,263 $ (397 ) $ 411 The accumulated benefit obligations for all U.S. and international pension plans were $11,954 and $4,676 , respectively, at December 31, 2016 , and $12,032 and $4,684 , respectively, at December 31, 2015 . Information for U.S. and international pension plans with an accumulated benefit obligation in excess of plan assets at December 31, 2016 and 2015 , was: Pension Benefits 2016 2015 U.S. Int’l. U.S. Int’l. Projected benefit obligations $ 13,208 $ 1,449 $ 13,500 $ 1,623 Accumulated benefit obligations 11,891 1,258 11,969 1,357 Fair value of plan assets 9,471 287 10,198 207 The components of net periodic benefit cost and amounts recognized in the Consolidated Statement of Comprehensive Income for 2016 , 2015 and 2014 are shown in the table below: Pension Benefits 2016 2015 2014 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2016 2015 2014 Net Periodic Benefit Cost Service cost $ 494 $ 159 $ 538 $ 185 $ 450 $ 190 $ 60 $ 72 $ 50 Interest cost 377 261 502 277 494 340 128 151 148 Expected return on plan assets (723 ) (243 ) (783 ) (262 ) (788 ) (298 ) — — — Amortization of prior service costs (credits) (9 ) 14 (8 ) 22 (9 ) 21 14 14 14 Recognized actuarial losses 335 47 356 78 209 96 19 34 7 Settlement losses 511 6 320 6 237 208 — — — Curtailment losses (gains) — — — (14 ) — — — — — Total net periodic benefit cost 985 244 925 292 593 557 221 271 219 Changes Recognized in Comprehensive Income Net actuarial (gain) loss during period 690 55 513 (260 ) 2,233 (17 ) (430 ) (362 ) 514 Amortization of actuarial loss (846 ) (53 ) (676 ) (84 ) (446 ) (304 ) (19 ) (34 ) (7 ) Prior service (credits) costs during period — — — (6 ) — 4 (345 ) — 2 Amortization of prior service (costs) credits 9 (14 ) 8 (24 ) 9 (21 ) (14 ) (14 ) (14 ) Total changes recognized in other (147 ) (12 ) (155 ) (374 ) 1,796 (338 ) (808 ) (410 ) 495 Recognized in Net Periodic Benefit Cost and Other Comprehensive Income $ 838 $ 232 $ 770 $ (82 ) $ 2,389 $ 219 $ (587 ) $ (139 ) $ 714 Net actuarial losses recorded in “Accumulated other comprehensive loss” at December 31, 2016 , for the company’s U.S. pension, international pension and OPEB plans are being amortized on a straight-line basis over approximately 10 , 12 and 11 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 2017 , the company estimates actuarial losses of $340 , $41 and $(5) 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 $408 will be recognized from “Accumulated other comprehensive loss” during 2017 related to lump-sum settlement costs from the main U.S. pension plans. The weighted average amortization period for recognizing prior service costs (credits) recorded in “Accumulated other comprehensive loss” at December 31, 2016 , was approximately 4 and 10 years for U.S. and international pension plans, respectively, and 11 years for OPEB plans. During 2017 , the company estimates prior service (credits) costs of $(5) , $12 and $(28) 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 2016 2015 2014 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2016 2015 2014 Assumptions used to determine benefit obligations: Discount rate 3.9 % 4.3 % 4.0 % 5.3 % 3.7 % 5.0 % 4.3 % 4.6 % 4.3 % Rate of compensation increase 4.5 % 4.5 % 4.5 % 4.8 % 4.5 % 5.1 % N/A N/A N/A Assumptions used to determine net periodic benefit cost: Discount rate for service cost 4.4 % 5.3 % 3.7 % 5.0 % 4.3 % 5.8 % 4.9 % 4.3 % 4.9 % Discount rate for interest cost 3.0 % 5.3 % 3.7 % 5.0 % 4.3 % 5.8 % 4.0 % 4.3 % 4.9 % Expected return on plan assets 7.3 % 6.3 % 7.5 % 6.3 % 7.5 % 6.6 % N/A N/A N/A Rate of compensation increase 4.5 % 4.8 % 4.5 % 5.1 % 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 2016 , the company used an expected long-term rate of return of 7.25 percent for U.S. pension plan assets, which account for 69 percent of the company’s pension plan assets. In both 2015 and 2014 , 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. Beginning with the December 31, 2015 measurement date, 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 at the end of 2016 were 3.9 percent for the main U.S. pension plan and 4.1 percent for the main U.S. OPEB plan. The discount rates for these plans at the end of 2015 were 4.0 and 4.5 percent , respectively, while in 2014 they were 3.7 and 4.1 percent for these plans, respectively. Beginning with the fiscal year ended December 31, 2016, the company changed the method used to estimate the service and interest cost associated with the company's main U.S. pension and OPEB plans. Under the new method, these costs are estimated by applying spot rates along the yield curve to the relevant projected cash flows. 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. Other Benefit Assumptions For the measurement of accumulated postretirement benefit obligation at December 31, 2016 , for the main U.S. OPEB plan, the assumed health care cost-trend rates start with 6.9 percent in 2017 and gradually decline to 4.5 percent for 2025 and beyond. For this measurement at December 31, 2015 , the assumed health care cost-trend rates started with 7.1 percent in 2016 and gradually declined to 4.5 percent for 2025 and beyond. In both measurements, the annual increase to the company's pre-Medicare contributions upon retirement 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 pre-Medicare 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 $ 17 $ (15 ) Effect on postretirement benefit obligation $ 156 $ (128 ) Plan Assets and Investment Strategy The fair value measurements of the company’s pension plans for 2016 and 2015 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, 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 At December 31, 2016 Equities U.S. 1 $ 1,217 $ 1,217 $ — $ — $ 565 $ 564 $ 1 $ — International 1,832 1,822 10 — 576 576 — — Collective Trusts/Mutual Funds 2 1,132 24 1,108 — 196 8 188 — Fixed Income Government 222 — 222 — 1,125 51 1,074 — Corporate 1,356 — 1,356 — 628 22 587 19 Bank Loans 118 — 107 11 — — — — Mortgage-Backed Securities 1 — 1 — 10 — 10 — Other Asset Backed — — — — — — — — Collective Trusts/Mutual Funds 2 1,031 — 1,031 — 320 — 320 — Mixed Funds 3 — — — — 72 2 70 — Real Estate 4 1,367 — — 1,367 331 — — 331 Alternative Investments 6 955 — 955 — — — — — Cash and Cash Equivalents 252 243 9 — 331 325 6 — Other 5 67 (9 ) 25 51 20 — 18 2 Total at December 31, 2016 $ 9,550 $ 3,297 $ 4,824 $ 1,429 $ 4,174 $ 1,548 $ 2,274 $ 352 1 U.S. equities include investments in the company’s common stock in the amount of $12 at December 31, 2016 , and $9 at December 31, 2015 . 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). 6 Alternative investments focus on market-neutral strategies that have a low expected correlation to traditional asset classes. For these funds, the level 2 designation is mainly based on the restriction that advanced notification of redemptions, typically thirty days or less, is required. The effects of fair value measurements using significant unobservable inputs on changes in Level 3 plan assets are outlined below: Fixed Income Corporate Bank Loans Real Estate Other Total 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 Actual Return on Plan Assets: Assets held at the reporting date 1 — (85 ) (1 ) (85 ) Assets sold during the period — — 121 1 122 Purchases, Sales and Settlements (7 ) 11 (210 ) (1 ) (207 ) Transfers in and/or out of Level 3 — — — — — Total at December 31, 2016 $ 19 $ 11 $ 1,698 $ 53 $ 1,781 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 90 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 30 – 60 percent , Fixed Income and Cash 20 – 65 percent , Real Estate 0 – 15 percent , and Alternative Investments 0 – 15 percent . The Alternative Investments range was expanded in 2016 to further diversify the portfolio. 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 – 70 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 factors, including market conditions and illiquidity constraints. 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 2016 , the company contributed $406 and $464 to its U.S. and international pension plans, respectively. In 2017 , the company expects contributions to be approximately $200 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, tax law changes 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 $163 in 2017 ; $189 was paid in 2016 . 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 2017 $ 1,502 $ 253 $ 163 2018 $ 1,362 $ 378 $ 163 2019 $ 1,310 $ 276 $ 164 2020 $ 1,267 $ 288 $ 164 2021 $ 1,234 $ 273 $ 164 2022-2026 $ 5,536 $ 1,542 $ 799 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 $281 , $316 and $316 in 2016 , 2015 and 2014 , respectively. 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 2016 , 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, 2016 and 2015 , trust assets of $35 and $36 , 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 $662 , $690 and $965 in 2016 , 2015 and 2014 , 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 2 3 , beginning on page FS-55 .

Other Contingencies and Commitm

Other Contingencies and Commitments	12 Months Ended
	Dec. 31, 2016
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 1 9 , beginning on page FS-49 , 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 has two guarantees to equity affiliates totaling $1,157 . Of this amount, $749 is associated with a financing arrangement with an equity affiliate. Over the approximate 5 -year remaining term of this guarantee, the maximum amount will be reduced as payments are made by the affiliate. The remaining amount of $408 is associated with certain payments under a terminal use agreement entered into by an equity affiliate. Over the approximate 11 -year remaining term of this 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 either 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: 2017 – $1,527 ; 2018 – $1,566 ; 2019 – $1,389 ; 2020 – $1,071 ; 2021 – $968 ; 2022 and after – $2,572 . A portion of these commitments may ultimately be shared with project partners. Total payments under the agreements were approximately $1,300 in 2016 , $1,900 in 2015 and $3,700 in 2014 . 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, 2016 , was $1,467 . Included in this balance was $284 related to remediation activities at approximately 146 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 2016 environmental reserves balance of $1,183 , $808 is related to the company’s U.S. downstream operations, $51 to its international downstream operations, $322 to upstream operations and $2 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 2016 had a recorded liability that was material to the company’s results of operations, consolidated financial position or liquidity. Refer to Note 2 6 on page FS-62 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; joint venture 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, 2016
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 2016 , 2015 and 2014 : 2016 2015 2014 Balance at January 1 $ 15,642 $ 15,053 $ 14,298 Liabilities incurred 204 51 133 Liabilities settled (1,658 ) (981 ) (1,291 ) Accretion expense 749 715 882 Revisions in estimated cash flows (694 ) 804 1,031 Balance at December 31 $ 14,243 $ 15,642 $ 15,053 In the table above, the amount associated with "Revisions in estimated cash flows" in 2016 reflects decreased cost estimates to abandon wells, equipment and facilities and delayed timing of abandonment. The long-term portion of the $14,243 balance at the end of 2016 was $13,447 .

Restructuring and Reorganizatio

Restructuring and Reorganization Costs	12 Months Ended
	Dec. 31, 2016
Restructuring and Related Activities [Abstract]
Restructuring and Reorganization Costs	Restructuring and Reorganization Costs In 2015 and early 2016, the company recorded accruals for employee reduction programs related to the restructuring and reorganization of its corporate staffs and certain upstream operations. The employee reduction programs are substantially completed and the remaining payments are anticipated to be made in early 2017. A before-tax charge of $353 was recorded in 2015 associated with these programs, of which $293 remained outstanding at December 31, 2015. During 2016 , the company recorded an additional before-tax charge of $83 and made payments of $316 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, 2016 $ 293 Accruals/Adjustments 83 Payments (316 ) Balance at December 31, 2016 $ 60

Other Financial Information

Other Financial Information	12 Months Ended
	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Other Financial Information	Other Financial Information Earnings in 2016 included after-tax gains of approximately $800 relating to the sale of certain properties. Of this amount, approximately $600 and $200 related to downstream and upstream, respectively. Earnings in 2015 included after-tax gains of approximately $2,300 relating to the sale of certain properties, of which approximately $ 1,800 and $500 related to downstream and upstream assets, respectively. Earnings in 2016 included after-tax charges of approximately $2,900 for impairments and other asset write-offs related to upstream, and $110 related to downstream. Earnings in 2015 included after-tax charges of approximately $3,000 for impairments and other asset write-offs related to upstream. Other financial information is as follows: Year ended December 31 2016 2015 2014 Total financing interest and debt costs $ 753 $ 495 $ 358 Less: Capitalized interest 552 495 358 Interest and debt expense $ 201 $ — $ — Research and development expenses $ 476 $ 601 $ 707 Excess of replacement cost over the carrying value of inventories (LIFO method) 2,942 3,745 8,135 LIFO (losses) / profits on inventory drawdowns included in earnings (88 ) (65 ) 13 Foreign currency effects * $ 58 $ 769 $ 487 * Includes $1 , $344 and $118 in 2016 , 2015 and 2014 , respectively, for the company’s share of equity affiliates’ foreign currency effects. The company has $4,581 in goodwill on the Consolidated Balance Sheet related primarily to the 2005 acquisition of Unocal. The company tested this goodwill for impairment during 2016 and no impairment was required.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2016
Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	Schedule II — Valuation and Qualifying Accounts Year ended December 31 Millions of Dollars 2016 2015 2014 Employee Termination Benefits Balance at January 1 $ 308 $ 49 $ 14 Additions (reductions) charged to expense 160 342 53 Payments (357 ) (83 ) (18 ) Balance at December 31 $ 111 $ 308 $ 49 Allowance for Doubtful Accounts Balance at January 1 $ 429 $ 194 $ 95 Additions to expense 76 251 119 Bad debt write-offs (18 ) (16 ) (20 ) Balance at December 31 $ 487 $ 429 $ 194 Deferred Income Tax Valuation Allowance * Balance at January 1 $ 15,412 $ 16,292 $ 17,171 Additions to deferred income tax expense 1,810 1,440 1,192 Reduction of deferred income tax expense (1,153 ) (2,320 ) (2,071 ) Balance at December 31 $ 16,069 $ 15,412 $ 16,292 * See also Note 1 9 to the Consolidated Financial Statements, beginning on page FS-49 .

Summary of Significant Accoun38

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
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 2 2 , beginning on page FS-54, 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 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 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 10 , beginning on page FS-37 , 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 2 6 , on page FS-62 , 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. Effective in the quarter ended December 31, 2016, the company has elected to move the annual review of the goodwill balance from the third to fourth quarter to better align with the preparation and review of the company's business plan, which is used in the test. The change does not delay, accelerate or avoid an impairment charge.
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 2 6 , on page FS-62 , 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-25 . 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 in the first, second and third anniversaries of the date of grant. Beginning in 2017, stock options and stock appreciation rights granted under the company’s Long-Term Incentive Plan have graded vesting by which one third of each award vests annually on each January 31 on or after the first anniversary of the grant date. Standard restricted stock units have cliff vesting by which the total award will vest on January 31 on or after the fifth anniversary of the grant date. The company amortizes these awards on a straight-line basis.
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 (Loss) 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 39

Changes in Accumulated Other Comprehensive Losses (Tables)	12 Months Ended
	Dec. 31, 2016
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, 2016 , are reflected in the table below. Year Ended December 31, 2016 1 Currency Translation Adjustment Unrealized Holding Gains (Losses) on Securities Derivatives Defined Benefit Plans Total Balance at January 1 $ (140 ) $ (29 ) $ (2 ) $ (4,120 ) $ (4,291 ) Components of Other Comprehensive Income (Loss): Before Reclassifications (22 ) 27 — (161 ) (156 ) Reclassifications 2 — — — 604 604 Net Other Comprehensive Income (Loss) (22 ) 27 — 443 448 Balance at December 31 $ (162 ) $ (2 ) $ (2 ) $ (3,677 ) $ (3,843 ) 1 All amounts are net of tax. 2 Refer to Note 24 beginning on page FS-56, for reclassified components totaling $937 that are included in employee benefit costs for the year ending December 31, 2016 . Related income taxes for the same period, totaling $333 , 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, 2016
Noncontrolling Interest [Abstract]
Activity for equity attributable to noncontrolling interests	Activity for the equity attributable to noncontrolling interests for 2016 , 2015 and 2014 is as follows: 2016 2015 2014 Balance at January 1 $ 1,170 $ 1,163 $ 1,314 Net income 66 123 69 Distributions to noncontrolling interests (63 ) (128 ) (47 ) Other changes, net (7 ) 12 (173 ) Balance at December 31 $ 1,166 $ 1,170 $ 1,163

Information Relating to the C41

Information Relating to the Consolidated Statement of Cash Flows (Tables)	12 Months Ended
	Dec. 31, 2016
Supplemental Cash Flow Elements [Abstract]
Schedule of information relating to the consolidated statement of cash flows	Year ended December 31 2016 2015 2014 Net increase in operating working capital was composed of the following: (Increase) decrease in accounts and notes receivable $ (2,121 ) $ 3,631 $ 4,491 Decrease (increase) in inventories 603 85 (146 ) Decrease (increase) in prepaid expenses and other current assets 439 713 (407 ) Increase (decrease) in accounts payable and accrued liabilities 533 (5,769 ) (3,737 ) Decrease in income and other taxes payable (4 ) (639 ) (741 ) Net increase in operating working capital $ (550 ) $ (1,979 ) $ (540 ) Net cash provided by operating activities includes the following cash payments for interest on debt and for income taxes: Interest on debt (net of capitalized interest) $ 158 $ — $ — Income taxes 1,935 4,645 10,562 Net sales (purchases) of marketable securities consisted of the following gross amounts: Marketable securities purchased $ (9 ) $ (6 ) $ (162 ) Marketable securities sold 306 128 14 Net sales (purchases) of marketable securities $ 297 $ 122 $ (148 ) Net maturities of time deposits consisted of the following gross amounts: Investments in time deposits $ — $ — $ (317 ) Maturities of time deposits — 8 317 Net maturities of time deposits $ — $ 8 $ — Net (borrowing) repayment of loans by equity affiliates: Borrowing of loans by equity affiliates $ (2,341 ) $ (223 ) $ (176 ) Repayment of loans by equity affiliates 307 6 316 Net (borrowing) repayment of loans by equity affiliates $ (2,034 ) $ (217 ) $ 140 Net sales (purchases) of other short-term investments: Purchases of other short-term investments $ (1 ) $ (75 ) $ (223 ) Sales of other short-term investments 218 119 16 Net sales (purchases) of other short-term investments $ 217 $ 44 $ (207 ) Net borrowings (repayments) of short-term obligations consisted of the following gross and net amounts: Proceeds from issuances of short-term obligations $ 14,778 $ 13,805 $ 9,070 Repayments of short-term obligations (12,558 ) (16,379 ) (4,612 ) Net borrowings (repayments) of short-term obligations with three months or less maturity (90 ) 2,239 (1,027 ) Net borrowings (repayments) of short-term obligations $ 2,130 $ (335 ) $ 3,431
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 2016 2015 2014 Additions to properties, plant and equipment * $ 17,742 $ 28,213 $ 34,393 Additions to investments 55 555 526 Current-year dry hole expenditures 313 736 504 Payments for other liabilities and assets, net (1 ) — (16 ) Capital expenditures 18,109 29,504 35,407 Expensed exploration expenditures 544 1,031 1,110 Assets acquired through capital lease obligations and other financing obligations 5 47 332 Capital and exploratory expenditures, excluding equity affiliates 18,658 30,582 36,849 Company's share of expenditures by equity affiliates 3,770 3,397 3,467 Capital and exploratory expenditures, including equity affiliates $ 22,428 $ 33,979 $ 40,316 * Excludes noncash additions of $56 in 2016 , $1,362 in 2015 and $2,310 in 2014 .

Lease Commitments (Tables)

Lease Commitments (Tables)	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Schedule of capitalized leased assets	Details of the capitalized leased assets are as follows: At December 31 2016 2015 Upstream $ 676 $ 800 Downstream 99 98 All Other — — Total 775 898 Less: Accumulated amortization 383 448 Net capitalized leased assets $ 392 $ 450
Rental expenses incurred for operating leases	Rental expenses incurred for operating leases during 2016 , 2015 and 2014 were as follows: Year ended December 31 2016 2015 2014 Minimum rentals $ 943 $ 1,041 $ 1,080 Contingent rentals 2 2 1 Total 945 1,043 1,081 Less: Sublease rental income 7 9 14 Net rental expense $ 938 $ 1,034 $ 1,067
Estimated future minimum lease payments (net of noncancelable sublease rentals) under operating and capital leases	At December 31, 2016 , 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 2017 $ 615 $ 22 2018 554 20 2019 387 21 2020 298 12 2021 235 12 Thereafter 392 145 Total $ 2,481 $ 232 Less: Amounts representing interest and executory costs $ (125 ) Net present values 107 Less: Capital lease obligations included in short-term debt (14 ) Long-term capital lease obligations $ 93

Summarized Financial Data - C43

Summarized Financial Data - Chevron U.S.A. Inc. (Tables)	12 Months Ended
	Dec. 31, 2016
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 2016 2015 2014 Sales and other operating revenues $ 83,715 $ 97,766 $ 157,198 Total costs and other deductions 87,429 101,565 153,139 Net income (loss) attributable to CUSA (1,177 ) (1,054 ) 3,849
Summarized Financial Data and its Subsidiary	2016 2015 * Current assets $ 11,266 $ 9,096 Other assets 55,722 59,171 Current liabilities 16,660 13,664 Other liabilities 21,701 28,465 Total CUSA net equity $ 28,627 $ 26,138 Memo: Total debt $ 9,418 $ 14,462 * 2015 adjusted to conform to ASU 2015-17 .

Summarized Financial Data - T44

Summarized Financial Data - Tengizchevroil LLP (Tables)	12 Months Ended
	Dec. 31, 2016
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 2016 2015 2014 Sales and other operating revenues $ 10,460 $ 12,811 $ 22,813 Costs and other deductions 6,822 7,257 10,275 Net income attributable to TCO 2,563 3,897 8,772
Summarized Financial Data and its Affiliate	At December 31 2016 2015 Current assets $ 7,001 $ 2,098 Other assets 20,476 17,094 Current liabilities 2,841 1,063 Other liabilities 6,210 2,266 Total TCO net equity $ 18,426 $ 15,863

Summarized Financial Data _ C45

Summarized Financial Data – Chevron Phillips Chemical Company LLC (Tables)	12 Months Ended
	Dec. 31, 2016
Summarized Financial Data of Subsidiary Two [Abstract]
Summarized Financial Data - Chevron Transport Corporation	Summarized financial information for 100 percent of CPChem is presented in the table below: Year ended December 31 2016 2015 2014 Sales and other operating revenues $ 8,455 $ 9,248 $ 13,416 Costs and other deductions 7,017 7,136 10,776 Net income attributable to CPChem 1,687 2,651 3,288
Summarized Financial Data and its Subsidiary	At December 31 2016 2015 Current assets $ 2,695 $ 2,291 Other assets 12,770 11,306 Current liabilities 1,418 1,319 Other liabilities 2,569 2,013 Total CPChem net equity $ 11,478 $ 10,265

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2016
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, 2016 At December 31, 2015 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Marketable securities $ 13 $ 13 $ — $ — $ 310 $ 310 $ — $ — Derivatives 32 15 17 — 205 189 16 — Total assets at fair value $ 45 $ 28 $ 17 $ — $ 515 $ 499 $ 16 $ — Derivatives 109 78 31 — 53 47 6 — Total liabilities at fair value $ 109 $ 78 $ 31 $ — $ 53 $ 47 $ 6 $ —
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 2016 Total Level 1 Level 2 Level 3 Year 2015 Properties, plant and equipment, net (held and used) $ 582 $ — $ 15 $ 567 $ 2,507 $ 3,051 $ — $ 239 $ 2,812 $ 3,222 Properties, plant and equipment, net (held for sale) 891 — 888 3 679 937 — 937 — 844 Investments and advances 26 — 20 6 234 75 — 75 — 28 Total nonrecurring assets at fair value $ 1,499 $ — $ 923 $ 576 $ 3,420 $ 4,063 $ — $ 1,251 $ 2,812 $ 4,094

Financial and Derivative Inst47

Financial and Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2016
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 2016 2015 Commodity Accounts and notes receivable, net $ 30 $ 200 Commodity Long-term receivables, net 2 5 Total assets at fair value $ 32 $ 205 Commodity Accounts payable $ 99 $ 51 Commodity Deferred credits and other noncurrent obligations 10 2 Total liabilities at fair value $ 109 $ 53
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 2016 2015 2014 Commodity Sales and other operating revenues $ (269 ) $ 277 $ 553 Commodity Purchased crude oil and products (31 ) 30 (17 ) Commodity Other income — (3 ) (32 ) $ (300 ) $ 304 $ 504
Consolidated Balance Sheet: The Effect of Netting Derivative Assets	The table on the following page represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at December 31, 2016 and December 31, 2015 . 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, 2016 Derivative Assets $ 1,052 $ 1,020 $ 32 $ — $ 32 Derivative Liabilities $ 1,129 $ 1,020 $ 109 $ — $ 109 At December 31, 2015 Derivative Assets $ 2,459 $ 2,254 $ 205 $ — $ 205 Derivative Liabilities $ 2,307 $ 2,254 $ 53 $ — $ 53
Consolidated Balance Sheet: The Effect of Netting Derivative Liabilities	The table on the following page represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at December 31, 2016 and December 31, 2015 . 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, 2016 Derivative Assets $ 1,052 $ 1,020 $ 32 $ — $ 32 Derivative Liabilities $ 1,129 $ 1,020 $ 109 $ — $ 109 At December 31, 2015 Derivative Assets $ 2,459 $ 2,254 $ 205 $ — $ 205 Derivative Liabilities $ 2,307 $ 2,254 $ 53 $ — $ 53

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2016
Earnings Per Share [Abstract]
Computation of basic and diluted EPS	Year ended December 31 2016 2015 2014 Basic EPS Calculation Earnings available to common stockholders - Basic 1 $ (497 ) $ 4,587 $ 19,241 Weighted-average number of common shares outstanding 2 1,872 1,867 1,883 Add: Deferred awards held as stock units 1 1 1 Total weighted-average number of common shares outstanding 1,873 1,868 1,884 Earnings per share of common stock - Basic $ (0.27 ) $ 2.46 $ 10.21 Diluted EPS Calculation Earnings available to common stockholders - Diluted 1 $ (497 ) $ 4,587 $ 19,241 Weighted-average number of common shares outstanding 2 1,872 1,867 1,883 Add: Deferred awards held as stock units 1 1 1 Add: Dilutive effect of employee stock-based awards — 7 14 Total weighted-average number of common shares outstanding 1,873 1,875 1,898 Earnings per share of common stock - Diluted $ (0.27 ) $ 2.45 $ 10.14 1 There was no effect of dividend equivalents paid on stock units or dilutive impact of employee stock-based awards on earnings. 2 Millions of shares; 10 million shares of employee-based awards were not included in the 2016 diluted EPS calculation as the result would be anti-dilutive.

Operating Segments and Geogra49

Operating Segments and Geographic Data (Tables)	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Segment Earnings	Earnings by major operating area are presented in the table on the following page: Year ended December 31 2016 2015 2014 Upstream United States $ (2,054 ) $ (4,055 ) $ 3,327 International (483 ) 2,094 13,566 Total Upstream (2,537 ) (1,961 ) 16,893 Downstream United States 1,307 3,182 2,637 International 2,128 4,419 1,699 Total Downstream 3,435 7,601 4,336 Total Segment Earnings 898 5,640 21,229 All Other Interest expense (168 ) — — Interest income 58 65 77 Other (1,285 ) (1,118 ) (2,065 ) Net Income (Loss) Attributable to Chevron Corporation $ (497 ) $ 4,587 $ 19,241
Segment Assets	Assets at year-end 2016 and 2015 are as follows: At December 31 2016 2015 Upstream United States 1 $ 42,596 $ 46,383 International 1 164,068 162,030 Goodwill 4,581 4,588 Total Upstream 211,245 213,001 Downstream United States 1 22,264 21,404 International 15,816 14,982 Total Downstream 38,080 36,386 Total Segment Assets 249,325 249,387 All Other United States 1,2 4,852 4,728 International 5,901 10,425 Total All Other 10,753 15,153 Total Assets – United States 1,2 69,712 72,515 Total Assets – International 1 185,785 187,437 Goodwill 4,581 4,588 Total Assets $ 260,078 $ 264,540 1 2015 adjusted to conform to ASU 2015-17. Refer to Note 1 9 , "Income Taxes" beginning on page FS-49 . 2 2015 adjusted to conform to ASU 2015-03. Refer to Note 5 , "New Accounting Standards" on page FS-34 .
Segment Sales and Other Operating Revenues	Year ended December 31 2016 2015 2014 Upstream United States $ 3,148 $ 4,117 $ 7,455 Intersegment 7,217 8,631 15,455 Total United States 10,365 12,748 22,910 International 13,262 15,587 23,808 Intersegment 9,518 11,492 23,107 Total International 22,780 27,079 46,915 Total Upstream 33,145 39,827 69,825 Downstream United States 40,366 48,420 73,942 Excise and similar taxes 4,335 4,426 4,633 Intersegment 16 26 31 Total United States 44,717 52,872 78,606 International 46,388 54,296 86,848 Excise and similar taxes 2,570 2,933 3,553 Intersegment 1,068 1,528 8,839 Total International 50,026 58,757 99,240 Total Downstream 94,743 111,629 177,846 All Other United States 145 141 252 Intersegment 960 1,372 1,475 Total United States 1,105 1,513 1,727 International 1 5 3 Intersegment 36 37 28 Total International 37 42 31 Total All Other 1,142 1,555 1,758 Segment Sales and Other Operating Revenues United States 56,187 67,133 103,243 International 72,843 85,878 146,186 Total Segment Sales and Other Operating Revenues 129,030 153,011 249,429 Elimination of intersegment sales (18,815 ) (23,086 ) (48,935 ) Total Sales and Other Operating Revenues $ 110,215 $ 129,925 $ 200,494
Segment income tax expense	Segment income tax expense for the years 2016 , 2015 and 2014 is as follows: Year ended December 31 2016 2015 2014 Upstream United States $ (1,172 ) $ (2,041 ) $ 2,043 International 166 1,214 9,217 Total Upstream (1,006 ) (827 ) 11,260 Downstream United States 503 1,320 1,302 International 484 1,313 467 Total Downstream 987 2,633 1,769 All Other (1,710 ) (1,674 ) (1,137 ) Total Income Tax Expense (Benefit) $ (1,729 ) $ 132 $ 11,892

Investments and Advances (Table

Investments and Advances (Tables)	12 Months Ended
	Dec. 31, 2016
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 2016 2015 2016 2015 2014 Upstream Tengizchevroil $ 11,414 $ 8,077 $ 1,380 $ 1,939 $ 4,392 Petropiar 977 679 326 180 26 Caspian Pipeline Consortium 1,245 1,342 145 162 191 Petroboscan 982 1,163 (133 ) 219 186 Angola LNG Limited 2,744 3,284 (282 ) (417 ) (311 ) Other 1,791 2,158 (193 ) 135 229 Total Upstream 19,153 16,703 1,243 2,218 4,713 Downstream GS Caltex Corporation 3,767 3,620 373 824 420 Chevron Phillips Chemical Company LLC 5,767 5,196 840 1,367 1,606 Caltex Australia Ltd. — — — 92 183 Other 1,118 1,077 209 186 180 Total Downstream 10,652 9,893 1,422 2,469 2,389 All Other Other (16 ) (18 ) (4 ) (3 ) (4 ) Total equity method $ 29,789 $ 26,578 $ 2,661 $ 4,684 $ 7,098 Other at or below cost 461 532 Total investments and advances $ 30,250 $ 27,110 Total United States $ 7,258 $ 6,863 $ 802 $ 1,342 $ 1,623 Total International $ 22,992 $ 20,247 $ 1,859 $ 3,342 $ 5,475
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 $3,535 , $410 and $874 at December 31, 2016 , 2015 and 2014 , respectively. Affiliates Chevron Share Year ended December 31 2016 2015 2014 2016 2015 2014 Total revenues $ 59,253 $ 71,389 $ 123,003 $ 27,787 $ 33,492 $ 58,937 Income before income tax expense 6,587 13,129 20,609 3,670 6,279 9,968 Net income attributable to affiliates 5,127 10,649 14,758 2,876 4,691 7,237 At December 31 Current assets $ 33,406 $ 27,162 $ 35,662 $ 13,743 $ 10,657 $ 13,465 Noncurrent assets 75,258 71,650 70,817 28,854 26,607 26,053 Current liabilities 24,793 20,559 25,308 8,996 7,351 9,588 Noncurrent liabilities 22,671 18,560 17,983 4,255 3,909 4,211 Total affiliates' net equity $ 61,200 $ 59,693 $ 63,188 $ 29,346 $ 26,004 $ 25,719

Properties, Plant and Equipme51

Properties, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2016
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 2016 2015 2014 2016 2015 2014 2016 2015 2014 2016 2015 2014 Upstream United States $ 83,929 $ 93,848 $ 96,850 $ 39,710 $ 43,125 $ 45,864 $ 4,432 $ 6,586 $ 9,688 $ 6,576 $ 8,545 $ 5,127 International 214,557 208,395 192,637 125,502 127,459 118,926 12,084 19,993 24,920 11,247 10,803 9,688 Total Upstream 298,486 302,243 289,487 165,212 170,584 164,790 16,516 26,579 34,608 17,823 19,348 14,815 Downstream United States 22,795 23,202 22,640 10,196 10,807 11,019 528 696 588 956 878 886 International 9,350 9,177 9,334 4,094 4,090 4,219 375 365 530 332 355 396 Total Downstream 32,145 32,379 31,974 14,290 14,897 15,238 903 1,061 1,118 1,288 1,233 1,282 All Other United States 5,263 5,500 5,673 2,635 2,859 3,077 198 357 581 328 439 680 International 183 155 155 49 56 68 6 5 25 18 17 16 Total All Other 5,446 5,655 5,828 2,684 2,915 3,145 204 362 606 346 456 696 Total United States 111,987 122,550 125,163 52,541 56,791 59,960 5,158 7,639 10,857 7,860 9,862 6,693 Total International 224,090 217,727 202,126 129,645 131,605 123,213 12,465 20,363 25,475 11,597 11,175 10,100 Total $ 336,077 $ 340,277 $ 327,289 $ 182,186 $ 188,396 $ 183,173 $ 17,623 $ 28,002 $ 36,332 $ 19,457 $ 21,037 $ 16,793 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 2016 . Australia had PP&E of $53,962 , $49,205 and $41,012 in 2016 , 2015 , and 2014 , respectively. Nigeria had PP&E of $17,922 , $18,773 and $19,214 for 2016 , 2015 and 2014 , respectively. 2 Net of dry hole expense related to prior years’ expenditures of $175 , $1,573 and $371 in 2016 , 2015 and 2014 , respectively. 3 Depreciation expense includes accretion expense of $749 , $715 and $882 in 2016 , 2015 and 2014 , respectively, and impairments of $3,186 , $4,066 and $1,274 in 2016 , 2015 and 2014 , respectively.

Taxes (Tables)

Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Taxes on income	Income Taxes Year ended December 31 2016 2015 2014 Income tax expense (benefit) U.S. federal Current $ (623 ) $ (817 ) $ 748 Deferred (1,558 ) (580 ) 1,330 State and local Current (15 ) (187 ) 336 Deferred (121 ) (109 ) 36 Total United States (2,317 ) (1,693 ) 2,450 International Current 2,744 2,997 9,235 Deferred (2,156 ) (1,172 ) 207 Total International 588 1,825 9,442 Total income tax expense (benefit) $ (1,729 ) $ 132 $ 11,892
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: 2016 2015 1 2014 1 Income (loss) before income taxes United States $ (4,317 ) $ (2,877 ) $ 6,296 International 2,157 7,719 24,906 Total income (loss) before income taxes (2,160 ) 4,842 31,202 Theoretical tax (at U.S. statutory rate of 35%) (756 ) 1,695 10,921 Equity affiliate accounting effect (704 ) (1,286 ) (2,039 ) Effect of income taxes from international operations 608 72 2,708 State and local taxes on income, net of U.S. federal income tax benefit (44 ) (74 ) 234 Prior year tax adjustments, claims and settlements (349 ) 84 (76 ) Tax credits (188 ) (35 ) (68 ) Other 2 (296 ) (324 ) 212 Total income tax expense (benefit) $ (1,729 ) $ 132 $ 11,892 Effective income tax rate 80.0 % 2.7 % 38.1 % 1 2014 and 2015 conformed to 2016 presentation. 2 Includes one-time tax benefits associated with changes in uncertain tax positions and valuation allowances.
Composition of deferred tax balances	The reported deferred tax balances are composed of the following: At December 31 2016 2015 Deferred tax liabilities Properties, plant and equipment $ 25,180 $ 27,044 Investments and other 5,222 3,743 Total deferred tax liabilities 30,402 30,787 Deferred tax assets Foreign tax credits (10,976 ) (10,534 ) Abandonment/environmental reserves (6,251 ) (6,880 ) Employee benefits (4,392 ) (4,801 ) Deferred credits (1,950 ) (1,810 ) Tax loss carryforwards (6,030 ) (2,748 ) Other accrued liabilities (510 ) (525 ) Inventory (374 ) (120 ) Miscellaneous (3,121 ) (2,525 ) Total deferred tax assets (33,604 ) (29,943 ) Deferred tax assets valuation allowance 16,069 15,412 Total deferred taxes, net $ 12,867 $ 16,256
Classification of deferred taxes	At December 31, 2016 and 2015 , deferred taxes were classified on the Consolidated Balance Sheet as follows: At December 31 2016 2015 Deferred charges and other assets $ (4,649 ) $ (3,909 ) Noncurrent deferred income taxes 17,516 20,165 Total deferred income taxes, net $ 12,867 $ 16,256
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, 2016 , 2015 and 2014 . 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. 2016 2015 2014 Balance at January 1 $ 3,042 $ 3,552 $ 3,848 Foreign currency effects 1 (27 ) (25 ) Additions based on tax positions taken in current year 245 154 354 Additions/reductions resulting from current-year asset acquisitions/sales — — (22 ) Additions for tax positions taken in prior years 181 218 37 Reductions for tax positions taken in prior years (390 ) (678 ) (561 ) Settlements with taxing authorities in current year (36 ) (5 ) (50 ) Reductions as a result of a lapse of the applicable statute of limitations (12 ) (172 ) (29 ) Balance at December 31 $ 3,031 $ 3,042 $ 3,552
Taxes other than on income	Taxes Other Than on Income Year ended December 31 2016 2015 2014 United States Excise and similar taxes on products and merchandise $ 4,335 $ 4,426 $ 4,633 Import duties and other levies 9 4 6 Property and other miscellaneous taxes 1,680 1,367 1,002 Payroll taxes 252 270 273 Taxes on production 159 157 349 Total United States 6,435 6,224 6,263 International Excise and similar taxes on products and merchandise 2,570 2,933 3,553 Import duties and other levies 33 40 45 Property and other miscellaneous taxes 2,379 2,548 2,277 Payroll taxes 145 161 172 Taxes on production 106 124 230 Total International 5,233 5,806 6,277 Total taxes other than on income $ 11,668 $ 12,030 $ 12,540

Short-Term Debt (Tables)

Short-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Short-Term Debt	At December 31 2016 2015 Commercial paper 1 $ 10,410 $ 8,252 Notes payable to banks and others with originating terms of one year or less 50 20 Current maturities of long-term debt 2 6,253 1,486 Current maturities of long-term capital leases 14 17 Redeemable long-term obligations Long-term debt 3,113 3,152 Capital leases — — Subtotal 19,840 12,927 Reclassified to long-term debt (9,000 ) (8,000 ) Total short-term debt $ 10,840 $ 4,927 1 Weighted-average interest rates at December 31, 2016 and 2015, were 0.74 percent and 0.26 percent, respectively. 2 2015 adjusted to conform to ASU 2015-03. Refer to Note 5, "New Accounting Standards" on page FS-34.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Long-term debt outstanding	The company’s long-term debt outstanding at year-end 2016 and 2015 was as follows: At December 31 2016 2015 Principal Unamortized discounts and debt issuance costs Principal Unamortized discounts and debt issuance costs 3.191% notes due 2023 $ 2,250 $ 4 $ 2,250 $ 4 2.954% notes due 2026 2,250 6 — — Floating rate notes due 2017 (1.091%) 1 2,050 1 2,050 2 1.104% notes due 2017 2,000 1 2,000 2 1.718% notes due 2018 2,000 1 2,000 2 2.355% notes due 2022 2,000 5 2,000 5 1.365% notes due 2018 1,750 1 1,750 2 1.961% notes due 2020 1,750 2 1,750 2 Floating rate notes due 2018 (1.310%) 1 1,650 2 800 1 4.95% notes due 2019 1,500 2 1,500 2 1.561% notes due 2019 1,350 2 — — 2.100% notes due 2021 1,350 2 — — 1.790% notes due 2018 1,250 1 1,250 2 2.419% notes due 2020 1,250 2 1,250 2 1.345% notes due 2017 1,100 — 1,100 2 1.344% notes due 2017 1,000 1 1,000 1 2.427% notes due 2020 1,000 1 1,000 2 2.193% notes due 2019 750 1 750 1 2.566% notes due 2023 750 1 — — 3.326% notes due 2025 750 2 750 2 2.411% notes due 2022 700 1 700 1 Floating rate notes due 2021 (1.599%) 1 650 1 400 1 Floating rate notes due 2019 (1.316%) 2 400 1 400 2 Floating rate notes due 2022 (1.472%) 2 350 — 350 1 Amortizing bank loan due 2018 (1.527%) 1 178 — 110 — 8.625% debentures due 2032 147 1 147 1 8.625% debentures due 2031 108 1 108 1 8% debentures due 2032 75 1 74 1 9.75% debentures due 2020 54 — 54 — 8.875% debentures due 2021 40 — 40 — Medium-term notes, maturing from 2021 to 2038 (6.133%) 1 38 — 38 — 0.889% notes due 2016 — — 750 — Floating rate notes due 2016 — — 700 1 Total including debt due within one year 32,490 44 27,071 43 Debt due within one year (6,256 ) (3 ) (1,487 ) (1 ) Reclassified from short-term debt 9,000 8,000 Total long-term debt $ 35,234 $ 41 $ 33,584 $ 42 1 Weighted-average interest rate at December 31, 2016 . 2 Interest rate at December 31, 2016.

Accounting for Suspended Expl55

Accounting for Suspended Exploratory Wells (Tables)	12 Months Ended
	Dec. 31, 2016
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, 2016 : 2016 2015 2014 Beginning balance at January 1 $ 3,312 $ 4,195 $ 3,245 Additions to capitalized exploratory well costs pending the determination of proved reserves 465 869 1,591 Reclassifications to wells, facilities and equipment based on the determination of proved reserves (119 ) (164 ) (298 ) Capitalized exploratory well costs charged to expense (118 ) (1,397 ) (312 ) Other reductions * — (191 ) (31 ) Ending balance at December 31 $ 3,540 $ 3,312 $ 4,195 * 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 2016 2015 2014 Exploratory well costs capitalized for a period of one year or less $ 445 $ 489 $ 1,522 Exploratory well costs capitalized for a period greater than one year 3,095 2,823 2,673 Balance at December 31 $ 3,540 $ 3,312 $ 4,195 Number of projects with exploratory well costs that have been capitalized for a period greater than one year * 35 39 51 * Certain projects have multiple wells or fields or both.
Aging of Costs on Well and Project Basis	(a) $190 ( two projects) – undergoing front-end engineering and design with final inve

Stock Options and Other Share56

Stock Options and Other Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2016
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 2016 , 2015 and 2014 were measured on the date of grant using the Black-Scholes option-pricing model, with the following weighted-average assumptions: Year ended December 31 2016 2015 2014 Expected term in years 1 6.3 6.1 6.0 Volatility 2 21.7 % 21.9 % 30.3 % Risk-free interest rate based on zero coupon U.S. treasury note 1.6 % 1.4 % 1.9 % Dividend yield 4.5 % 3.6 % 3.3 % Weighted-average fair value per option granted $ 9.53 $ 13.89 $ 25.86 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 2016 is presented below: Shares (Thousands) Weighted-Average Exercise Price Averaged Remaining Contractual Term (Years) Aggregate Intrinsic Value Outstanding at January 1, 2016 94,292 $ 96.67 Granted 30,913 $ 83.31 Exercised (8,589 ) $ 75.57 Forfeited (4,341 ) $ 86.81 Outstanding at December 31, 2016 112,275 $ 94.99 6.13 $ 2,550 Exercisable at December 31, 2016 71,153 $ 97.32 4.66 $ 1,450

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2016
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 2016 and 2015 follows: Pension Benefits 2016 2015 Other Benefits U.S. Int’l. U.S. Int’l. 2016 2015 Change in Benefit Obligation Benefit obligation at January 1 $ 13,563 $ 5,336 $ 14,250 $ 5,767 $ 3,324 $ 3,660 Service cost 494 159 538 185 60 72 Interest cost 377 261 502 277 128 151 Plan participants' contributions — 5 — 6 148 148 Plan amendments — — — (6 ) (345 ) — Actuarial (gain) loss 903 426 (345 ) (309 ) (437 ) (326 ) Foreign currency exchange rate changes — (524 ) — (326 ) 8 (37 ) Benefits paid (2,066 ) (494 ) (1,382 ) (241 ) (337 ) (344 ) Curtailment — — — (17 ) — — Benefit obligation at December 31 13,271 5,169 13,563 5,336 2,549 3,324 Change in Plan Assets Fair value of plan assets at January 1 10,274 4,109 11,090 4,244 — — Actual return on plan assets 936 642 (75 ) 112 — — Foreign currency exchange rate changes — (552 ) — (239 ) — — Employer contributions 406 464 641 227 189 196 Plan participants' contributions — 5 — 6 148 148 Benefits paid (2,066 ) (494 ) (1,382 ) (241 ) (337 ) (344 ) Fair value of plan assets at December 31 9,550 4,174 10,274 4,109 — — Funded status at December 31 $ (3,721 ) $ (995 ) $ (3,289 ) $ (1,227 ) $ (2,549 ) $ (3,324 )
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, 2016 and 2015 , include: Pension Benefits 2016 2015 Other Benefits U.S. Int’l. U.S. Int’l. 2016 2015 Deferred charges and other assets $ 16 $ 199 $ 13 $ 333 $ — $ — Accrued liabilities (222 ) (75 ) (153 ) (77 ) (163 ) (191 ) Noncurrent employee benefit plans (3,515 ) (1,119 ) (3,149 ) (1,483 ) (2,386 ) (3,133 ) Net amount recognized at December 31 $ (3,721 ) $ (995 ) $ (3,289 ) $ (1,227 ) $ (2,549 ) $ (3,324 )
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 $5,511 and $6,478 at the end of 2016 and 2015 , respectively. These amounts consisted of: Pension Benefits 2016 2015 Other Benefits U.S. Int’l. U.S. Int’l. 2016 2015 Net actuarial loss $ 4,653 $ 1,145 $ 4,809 $ 1,143 $ (82 ) $ 367 Prior service (credit) costs 4 106 (5 ) 120 (315 ) 44 Total recognized at December 31 $ 4,657 $ 1,251 $ 4,804 $ 1,263 $ (397 ) $ 411
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, 2016 and 2015 , was: Pension Benefits 2016 2015 U.S. Int’l. U.S. Int’l. Projected benefit obligations $ 13,208 $ 1,449 $ 13,500 $ 1,623 Accumulated benefit obligations 11,891 1,258 11,969 1,357 Fair value of plan assets 9,471 287 10,198 207
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 2016 , 2015 and 2014 are shown in the table below: Pension Benefits 2016 2015 2014 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2016 2015 2014 Net Periodic Benefit Cost Service cost $ 494 $ 159 $ 538 $ 185 $ 450 $ 190 $ 60 $ 72 $ 50 Interest cost 377 261 502 277 494 340 128 151 148 Expected return on plan assets (723 ) (243 ) (783 ) (262 ) (788 ) (298 ) — — — Amortization of prior service costs (credits) (9 ) 14 (8 ) 22 (9 ) 21 14 14 14 Recognized actuarial losses 335 47 356 78 209 96 19 34 7 Settlement losses 511 6 320 6 237 208 — — — Curtailment losses (gains) — — — (14 ) — — — — — Total net periodic benefit cost 985 244 925 292 593 557 221 271 219 Changes Recognized in Comprehensive Income Net actuarial (gain) loss during period 690 55 513 (260 ) 2,233 (17 ) (430 ) (362 ) 514 Amortization of actuarial loss (846 ) (53 ) (676 ) (84 ) (446 ) (304 ) (19 ) (34 ) (7 ) Prior service (credits) costs during period — — — (6 ) — 4 (345 ) — 2 Amortization of prior service (costs) credits 9 (14 ) 8 (24 ) 9 (21 ) (14 ) (14 ) (14 ) Total changes recognized in other (147 ) (12 ) (155 ) (374 ) 1,796 (338 ) (808 ) (410 ) 495 Recognized in Net Periodic Benefit Cost and Other Comprehensive Income $ 838 $ 232 $ 770 $ (82 ) $ 2,389 $ 219 $ (587 ) $ (139 ) $ 714
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 2016 2015 2014 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2016 2015 2014 Assumptions used to determine benefit obligations: Discount rate 3.9 % 4.3 % 4.0 % 5.3 % 3.7 % 5.0 % 4.3 % 4.6 % 4.3 % Rate of compensation increase 4.5 % 4.5 % 4.5 % 4.8 % 4.5 % 5.1 % N/A N/A N/A Assumptions used to determine net periodic benefit cost: Discount rate for service cost 4.4 % 5.3 % 3.7 % 5.0 % 4.3 % 5.8 % 4.9 % 4.3 % 4.9 % Discount rate for interest cost 3.0 % 5.3 % 3.7 % 5.0 % 4.3 % 5.8 % 4.0 % 4.3 % 4.9 % Expected return on plan assets 7.3 % 6.3 % 7.5 % 6.3 % 7.5 % 6.6 % N/A N/A N/A Rate of compensation increase 4.5 % 4.8 % 4.5 % 5.1 % 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 $ 17 $ (15 ) Effect on postretirement benefit obligation $ 156 $ (128 )
Fair value measurements of the Company's pension plans	The fair value measurements of the company’s pension plans for 2016 and 2015 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, 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 At December 31, 2016 Equities U.S. 1 $ 1,217 $ 1,217 $ — $ — $ 565 $ 564 $ 1 $ — International 1,832 1,822 10 — 576 576 — — Collective Trusts/Mutual Funds 2 1,132 24 1,108 — 196 8 188 — Fixed Income Government 222 — 222 — 1,125 51 1,074 — Corporate 1,356 — 1,356 — 628 22 587 19 Bank Loans 118 — 107 11 — — — — Mortgage-Backed Securities 1 — 1 — 10 — 10 — Other Asset Backed — — — — — — — — Collective Trusts/Mutual Funds 2 1,031 — 1,031 — 320 — 320 — Mixed Funds 3 — — — — 72 2 70 — Real Estate 4 1,367 — — 1,367 331 — — 331 Alternative Investments 6 955 — 955 — — — — — Cash and Cash Equivalents 252 243 9 — 331 325 6 — Other 5 67 (9 ) 25 51 20 — 18 2 Total at December 31, 2016 $ 9,550 $ 3,297 $ 4,824 $ 1,429 $ 4,174 $ 1,548 $ 2,274 $ 352 1 U.S. equities include investments in the company’s common stock in the amount of $12 at December 31, 2016 , and $9 at December 31, 2015 . 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). 6 Alternative investments focus on market-neutral strategies that have a low expected correlation to traditional asset classes. For these funds, the level 2 designation is mainly based on the restriction that advanced notification of redemptions, typically thirty days or less, is required.
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 Bank Loans Real Estate Other Total 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 Actual Return on Plan Assets: Assets held at the reporting date 1 — (85 ) (1 ) (85 ) Assets sold during the period — — 121 1 122 Purchases, Sales and Settlements (7 ) 11 (210 ) (1 ) (207 ) Transfers in and/or out of Level 3 — — — — — Total at December 31, 2016 $ 19 $ 11 $ 1,698 $ 53 $ 1,781
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 2017 $ 1,502 $ 253 $ 163 2018 $ 1,362 $ 378 $ 163 2019 $ 1,310 $ 276 $ 164 2020 $ 1,267 $ 288 $ 164 2021 $ 1,234 $ 273 $ 164 2022-2026 $ 5,536 $ 1,542 $ 799

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2016
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 2016 , 2015 and 2014 : 2016 2015 2014 Balance at January 1 $ 15,642 $ 15,053 $ 14,298 Liabilities incurred 204 51 133 Liabilities settled (1,658 ) (981 ) (1,291 ) Accretion expense 749 715 882 Revisions in estimated cash flows (694 ) 804 1,031 Balance at December 31 $ 14,243 $ 15,642 $ 15,053

Restructuring and Reorganizat59

Restructuring and Reorganization Costs (Tables)	12 Months Ended
	Dec. 31, 2016
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, 2016 $ 293 Accruals/Adjustments 83 Payments (316 ) Balance at December 31, 2016 $ 60

Other Financial Information (Ta

Other Financial Information (Tables)	12 Months Ended
	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Other Financial Information	Other financial information is as follows: Year ended December 31 2016 2015 2014 Total financing interest and debt costs $ 753 $ 495 $ 358 Less: Capitalized interest 552 495 358 Interest and debt expense $ 201 $ — $ — Research and development expenses $ 476 $ 601 $ 707 Excess of replacement cost over the carrying value of inventories (LIFO method) 2,942 3,745 8,135 LIFO (losses) / profits on inventory drawdowns included in earnings (88 ) (65 ) 13 Foreign currency effects * $ 58 $ 769 $ 487 * Includes $1 , $344 and $118 in 2016 , 2015 and 2014 , respectively, for the company’s share of equity affiliates’ foreign currency effects.

Summary of Significant Accoun61

Summary of Significant Accounting Policies (Details Textual)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Maturity period of bank time deposits reported as time deposits, minimum	90 days

Changes in Accumulated Other 62

Changes in Accumulated Other Comprehensive Losses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at January 1	$ 152,716
Components of Other Comprehensive Income (Loss):
Before Reclassifications	(156)
Reclassifications	604
Other Comprehensive Gain (Loss), Net of Tax	448	$ 568	$ (1,280)
Balance at December 31	145,556	152,716
Income tax expense (benefit)	(1,729)	132	11,892
AOCI Attributable to Parent [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at January 1	(4,291)
Components of Other Comprehensive Income (Loss):
Balance at December 31	(3,843)	(4,291)
Currency Translation Adjustment [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at January 1	(140)
Components of Other Comprehensive Income (Loss):
Before Reclassifications	(22)
Reclassifications	0
Other Comprehensive Gain (Loss), Net of Tax	(22)	(44)	(73)
Balance at December 31	(162)	(140)
Unrealized Holding Gains (Losses) on Securities [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at January 1	(29)
Components of Other Comprehensive Income (Loss):
Before Reclassifications	27
Reclassifications	0
Other Comprehensive Gain (Loss), Net of Tax	27	(21)	(2)
Balance at December 31	(2)	(29)
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	0	(54)
Balance at December 31	(2)	(2)
Defined Benefit Plans [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at January 1	(4,120)
Components of Other Comprehensive Income (Loss):
Before Reclassifications	(161)
Reclassifications	604
Other Comprehensive Gain (Loss), Net of Tax	443	633	$ (1,151)
Balance at December 31	(3,677)	$ (4,120)
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	937
Income tax expense (benefit)	$ 333

Noncontrolling Interests (Detai

Noncontrolling Interests (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Activity for equity attributable to noncontrolling interests
Balance at January 1	$ 153,886	$ 156,191
Net Income (Loss)	(431)	4,710	$ 19,310
Balance at December 31	146,722	153,886	156,191
Noncontrolling Interests
Activity for equity attributable to noncontrolling interests
Balance at January 1	1,170	1,163	1,314
Net Income (Loss)	66	123	69
Distributions to noncontrolling interests	(63)	(128)	(47)
Other changes, net	(7)	12	(173)
Balance at December 31	$ 1,166	$ 1,170	$ 1,163

Information Relating to the C64

Information Relating to the Consolidated Statement of Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net increase in operating working capital was composed of the following:
(Increase) decrease in accounts and notes receivable	$ (2,121)	$ 3,631	$ 4,491
Decrease (increase) in inventories	603	85	(146)
Decrease (increase) in prepaid expenses and other current assets	439	713	(407)
Increase (decrease) in accounts payable and accrued liabilities	533	(5,769)	(3,737)
Decrease in income and other taxes payable	(4)	(639)	(741)
Net increase in operating working capital	(550)	(1,979)	(540)
Net cash provided by operating activities includes the following cash payments for interest on debt and for income taxes:
Interest on debt (net of capitalized interest)	158	0	0
Income taxes	1,935	4,645	10,562
Net sales (purchases) of marketable securities consisted of the following gross amounts:
Marketable securities purchased	(9)	(6)	(162)
Marketable securities sold	306	128	14
Net sales (purchases) of marketable securities	297	122	(148)
Net maturities of time deposits consisted of the following gross amounts:
Time deposits purchased	0	0	(317)
Time deposits matured	0	8	317
Net sales (purchases) of time deposits	0	8	0
Net (borrowing) repayment of loans by equity affiliates:
Borrowing of loans by equity affiliates	(2,341)	(223)	(176)
Repayment of loans by equity affiliates	307	6	316
Net (borrowing) repayment of loans by equity affiliates	(2,034)	(217)	140
Net sales (purchases) of other short-term investments:
Purchases of other short-term investments	(1)	(75)	(223)
Sales of other short-term investments	218	119	16
Net sales (purchases) of other short-term investments	217	44	(207)
Net borrowings (repayments) of short-term obligations consisted of the following gross and net amounts:
Proceeds from issuances of short-term obligations	14,778	13,805	9,070
Repayments of short-term obligations	(12,558)	(16,379)	(4,612)
Net borrowings (repayments) of short-term obligations with three months or less maturity	(90)	2,239	(1,027)
Net borrowings (repayments) of short-term obligations	2,130	(335)	3,431
Capital expenditures
Additions to properties, plant and equipment	17,742	28,213	34,393
Additions to investments	55	555	526
Current-year dry hole expenditures	313	736	504
Payments for other liabilities and assets, net	(1)	0	(16)
Capital expenditures	18,109	29,504	35,407
Expensed exploration expenditures	544	1,031	1,110
Assets acquired through capital lease obligations and other financing obligations	5	47	332
Capital and exploratory expenditures, excluding equity affiliates	18,658	30,582	36,849
Company's share of expenditures by equity affiliates	3,770	3,397	3,467
Capital and exploratory expenditures, including equity affiliates	$ 22,428	$ 33,979	$ 40,316

Information Relating to the C65

Information Relating to the Consolidated Statement of Cash Flows (Details 1) - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Supplemental Cash Flow Elements [Abstract]
Share repurchase price	$ 2	$ 2	$ 5,006
Stock repurchased during period, shares			41.5
Stock repurchased during period, value			$ 5,000
Non-cash reduction to property, plant and equipment		2,800
Noncash additions to properties, plant and equipment	$ 56	$ 1,362	$ 2,310

New Accounting Standards (Detai

New Accounting Standards (Details) - Accounting Standards Update 2015-03 [Member] $ in Millions	Dec. 31, 2015USD ($)
Deferred charges and other assets [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Deferred finance costs	$ (43)
Short-term Debt [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Deferred finance costs	1
Long-term Debt [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Deferred finance costs	$ 42

Lease Commitments (Details)

Lease Commitments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating Leased Assets [Line Items]
Non-cancelable term of operating and capital leases (in years)	1 year
Schedule of capitalized leased assets
Upstream	$ 676	$ 800
Downstream	99	98
All Other	0	0
Total	775	898
Less: Accumulated amortization	383	448
Net capitalized leased assets	392	450
Rental expenses incurred for operating leases
Minimum rentals	943	1,041	$ 1,080
Contingent rentals	2	2	1
Total	945	1,043	1,081
Less: Sublease rental income	7	9	14
Net rental expense	938	1,034	$ 1,067
Estimated future minimum lease payments (net of noncancelable sublease rentals) under operating and capital leases
Operating Leases, 2017	615
Capital Leases, 2017	22
Operating Leases, 2018	554
Capital Leases, 2018	20
Operating Leases, 2019	387
Capital Leases, 2019	21
Operating Leases, 2020	298
Capital Leases, 2020	12
Operating Leases, 2021	235
Capital Leases, 2021	12
Operating Leases, Thereafter	392
Capital Leases, Thereafter	145
Operating Leases, Total	2,481
Capital Leases, Total	232
Less: Amounts representing interest and executory costs	(125)
Net present values	107
Less: Capital lease obligations included in short-term debt	(14)
Long-term capital lease obligations	$ 93	$ 80
Maximum [Member]
Operating Leased Assets [Line Items]
Contingent rentals, renewal option term (in years)	25 years

Summarized Financial Data - C68

Summarized Financial Data - Chevron U.S.A. Inc. (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Subsidiary Statements Captions [Line Items]
Sales and other operating revenues	[1]	$ 110,215	$ 129,925	$ 200,494
Total costs and other deductions		116,632	133,635	180,768
Net income (loss) attributable to CUSA		(497)	4,587	19,241
Chevron U.S.A. Inc. [Member]
Subsidiary Statements Captions [Line Items]
Sales and other operating revenues		83,715	97,766	157,198
Total costs and other deductions		87,429	101,565	153,139
Net income (loss) attributable to CUSA		$ (1,177)	$ (1,054)	$ 3,849
[1]	Includes excise, value-added and similar taxes. $6,905; $7,359; $8,186.

Summarized Financial Data - C69

Summarized Financial Data - Chevron U.S.A. Inc. (Details 1) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Subsidiary Statements Captions [Line Items]
Current assets	$ 29,619	$ 34,430
Current liabilities	31,785	25,467
Total CUSA net equity	146,722	153,886	$ 156,191
Chevron U.S.A. Inc. [Member]
Subsidiary Statements Captions [Line Items]
Current assets	11,266	9,096
Other assets	55,722	59,171
Current liabilities	16,660	13,664
Other liabilities	21,701	28,465
Total CUSA net equity	28,627	26,138
Memo: Total debt	$ 9,418	$ 14,462

Summarized Financial Data - T70

Summarized Financial Data - Tengizchevroil LLP (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Affiliate Statements Captions [Line Items]
Percentage of affiliate by summarized financial information		100.00%
Tengizchevroil LLP [Member]
Affiliate Statements Captions [Line Items]
Percentage of affiliate by summarized financial information	100.00%
Sales and other operating revenues	$ 10,460	$ 12,811	$ 22,813
Costs and other deductions	6,822	7,257	10,275
Net income attributable to TCO	$ 2,563	$ 3,897	$ 8,772
Tengizchevroil LLP [Member]
Affiliate Statements Captions [Line Items]
Equity method investment, ownership percentage	50.00%

Summarized Financial Data - T71

Summarized Financial Data - Tengizchevroil LLP (Details 1) - Tengizchevroil LLP [Member] - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Affiliate Statements Captions [Line Items]
Current assets	$ 7,001	$ 2,098
Other assets	20,476	17,094
Current liabilities	2,841	1,063
Other liabilities	6,210	2,266
Total net equity	$ 18,426	$ 15,863

Summarized Financial Data _ C72

Summarized Financial Data – Chevron Phillips Chemical Company LLC (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Subsidiary Statements Captions [Line Items]
Percentage of affiliate by summarized financial information			100.00%
Summarized Financial Data - Chevron Transport Corporation
Sales and other operating revenues	[1]	$ 110,215	$ 129,925	$ 200,494
Total costs and other deductions		116,632	133,635	180,768
Net income (loss) attributable to Chevron Corporation		$ (497)	4,587	19,241
Chevron Phillips Chemical Company LLC [Member]
Subsidiary Statements Captions [Line Items]
Percentage of affiliate by summarized financial information		100.00%
Summarized Financial Data - Chevron Transport Corporation
Sales and other operating revenues		$ 8,455	9,248	13,416
Total costs and other deductions		7,017	7,136	10,776
Net income (loss) attributable to Chevron Corporation		$ 1,687	$ 2,651	$ 3,288
Chevron Phillips Chemical Company LLC [Member]
Subsidiary Statements Captions [Line Items]
Equity method investment, ownership percentage		50.00%
[1]	Includes excise, value-added and similar taxes. $6,905; $7,359; $8,186.

Summarized Financial Data _ C73

Summarized Financial Data – Chevron Phillips Chemical Company LLC (Details 1) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Subsidiary Statements Captions [Line Items]
Current assets	$ 29,619	$ 34,430
Current liabilities	31,785	25,467
Total CTC net deficit	146,722	153,886	$ 156,191
Chevron Phillips Chemical Company LLC [Member]
Subsidiary Statements Captions [Line Items]
Current assets	2,695	2,291
Other assets	12,770	11,306
Current liabilities	1,418	1,319
Other liabilities	2,569	2,013
Total CTC net deficit	$ 11,478	$ 10,265

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives	$ 32	$ 205
Derivatives	109	53
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	13	310
Derivatives	32	205
Total assets at fair value	45	515
Derivatives	109	53
Total liabilities at fair value	109	53
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	13	310
Derivatives	15	189
Total assets at fair value	28	499
Derivatives	78	47
Total liabilities at fair value	78	47
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	17	16
Total assets at fair value	17	16
Derivatives	31	6
Total liabilities at fair value	31	6
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 (Deta75

Fair Value Measurements (Details 1) - Fair Value, Measurements, Nonrecurring [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Properties, plant and equipment, net (held and used)	$ 582	$ 3,051
Properties, plant and equipment, net (held for sale)	891	937
Investments and advances	26	75
Total nonrecurring assets at fair value	1,499	4,063
Properties, plant and equipment, net (held and used), Before-Tax Loss	2,507	3,222
Properties, plant and equipment, net (held for sale), Before-Tax Loss	679	844
Investments and advances, Before-Tax Loss	234	28
Total nonrecurring assets at fair value, Before-Tax Loss	3,420	4,094
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)	15	239
Properties, plant and equipment, net (held for sale)	888	937
Investments and advances	20	75
Total nonrecurring assets at fair value	923	1,251
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Properties, plant and equipment, net (held and used)	567	2,812
Properties, plant and equipment, net (held for sale)	3	0
Investments and advances	6	0
Total nonrecurring assets at fair value	$ 576	$ 2,812

Fair Value Measurements (Deta76

Fair Value Measurements (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying/fair value of cash and cash equivalents	$ 6,988	$ 11,022	$ 12,785	$ 16,245
Carrying/fair value of investments not included in cash and cash equivalents	1,426	1,100
Carrying amount of long-term debt	32,490	27,071
Corporate Bond Securities [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of debt	25,860
Other Long-term Debt [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	26,193	25,542
Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying amount of long-term debt	$ 26,627	$ 25,884
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 Inst77

Financial and Derivative Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Total assets at fair value	$ 32	$ 205
Total liabilities at fair value	109	53
Commodity Contract [Member] | Accounts and notes receivable, net [Member]
Derivatives, Fair Value [Line Items]
Total assets at fair value	30	200
Commodity Contract [Member] | Long term receivables, net [Member]
Derivatives, Fair Value [Line Items]
Total assets at fair value	2	5
Commodity Contract [Member] | Accounts payable [Member]
Derivatives, Fair Value [Line Items]
Total liabilities at fair value	99	51
Commodity Contract [Member] | Deferred credits and other noncurrent obligations [Member]
Derivatives, Fair Value [Line Items]
Total liabilities at fair value	$ 10	$ 2

Financial and Derivative Inst78

Financial and Derivative Instruments Financial and Derivative Instruments (Details 1) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ (300)	$ 304	$ 504
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	(269)	277	553
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	(31)	30	(17)
Commodity Contract [Member] | Other Income [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ 0	$ (3)	$ (32)

Financial and Derivative Inst79

Financial and Derivative Instruments Financial and Derivative Instruments (Details 2) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Offsetting Assets [Abstract]
Derivative Asset, Gross Amount Recognized	$ 1,052	$ 2,459
Derivative Asset, Gross Amounts Offset	1,020	2,254
Derivative Asset, Net Amounts Presented	32	205
Derivative Asset, Gross Amounts Not Offset	0	0
Derivative Asset, Net Amount	32	205
Offsetting Liabilities [Abstract]
Derivative Liability, Gross Amount Recognized	1,129	2,307
Derivative Liability, Gross Amounts Offset	1,020	2,254
Derivative Liability, Net Amounts Presented	109	53
Derivative Liability, Gross Amounts Not Offset	0	0
Derivative Liability, Net Amount	$ 109	$ 53

Assets Held For Sale (Details)

Assets Held For Sale (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Assets held for sale	$ 4,119	$ 1,449
Held-for-sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Assets held for sale	$ 4,119

Equity (Details)

Equity (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Company's share of undistributed earnings for equity affiliates	$ 16,479	$ 15,010
Shares remaining available for issuance (in shares)	859,746
Shares available for issuance (in shares)	1,600,000
Chevron Long-Term Incentive Plan (LTIP) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares remaining available for issuance (in shares)	87,000,000
Shares available for issuance (in shares)	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, 2016	Dec. 31, 2015	Dec. 31, 2014
Basic EPS Calculation
Earnings available to common stockholders - Basic	$ (497)	$ 4,587	$ 19,241
Weighted-average number of common shares outstanding (in shares)	1,872	1,867	1,883
Add: Deferred awards held as stock units (in shares)	1	1	1
Total weighted-average number of common shares outstanding (in shares)	1,873	1,868	1,884
Earnings per share of common stock - Basic (in dollars per share)	$ (0.27)	$ 2.46	$ 10.21
Diluted EPS Calculation
Earnings available to common stockholders - Diluted	$ (497)	$ 4,587	$ 19,241
Weighted-average number of common shares outstanding (in shares)	1,872	1,867	1,883
Add: Deferred awards held as stock units (in shares)	1	1	1
Add: Dilutive effect of employee stock-based awards (in shares)	0	7	14
Total weighted-average number of common shares outstanding (in shares)	1,873	1,875	1,898
Earnings per share of common stock - Diluted (in dollars per share)	$ (0.27)	$ 2.45	$ 10.14
Employee-based Awards [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of EPS	10

Operating Segments and Geogra83

Operating Segments and Geographic Data (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Net income (loss) attributable to Chevron Corporation	$ (497)	$ 4,587	$ 19,241
Upstream [Member]
Segment Reporting Information [Line Items]
Net income (loss) attributable to Chevron Corporation	(2,537)	(1,961)	16,893
Downstream [Member]
Segment Reporting Information [Line Items]
Net income (loss) attributable to Chevron Corporation	3,435	7,601	4,336
Operating Segments [Member]
Segment Reporting Information [Line Items]
Net income (loss) attributable to Chevron Corporation	898	5,640	21,229
Operating Segments [Member] | Upstream [Member] | United States [Member]
Segment Reporting Information [Line Items]
Net income (loss) attributable to Chevron Corporation	(2,054)	(4,055)	3,327
Operating Segments [Member] | Upstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Net income (loss) attributable to Chevron Corporation	(483)	2,094	13,566
Operating Segments [Member] | Downstream [Member] | United States [Member]
Segment Reporting Information [Line Items]
Net income (loss) attributable to Chevron Corporation	1,307	3,182	2,637
Operating Segments [Member] | Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Net income (loss) attributable to Chevron Corporation	2,128	4,419	1,699
Segment Reconciling Items [Member]
Segment Reporting Information [Line Items]
Interest expense	(168)	0	0
Interest income	58	65	77
Other	$ (1,285)	$ (1,118)	$ (2,065)

Operating Segments and Geogra84

Operating Segments and Geographic Data (Details 1) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Total Assets	$ 260,078	$ 264,540
Goodwill	4,581	4,588
United States [Member]
Segment Reporting Information [Line Items]
Total Assets	69,712	72,515
International [Member]
Segment Reporting Information [Line Items]
Total Assets	185,785	187,437
Operating Segments [Member]
Segment Reporting Information [Line Items]
Total Assets	249,325	249,387
Operating Segments [Member] | Upstream [Member]
Segment Reporting Information [Line Items]
Total Assets	211,245	213,001
Goodwill	4,581	4,588
Operating Segments [Member] | Upstream [Member] | United States [Member]
Segment Reporting Information [Line Items]
Total Assets	42,596	46,383
Operating Segments [Member] | Upstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Total Assets	164,068	162,030
Operating Segments [Member] | Downstream [Member]
Segment Reporting Information [Line Items]
Total Assets	38,080	36,386
Operating Segments [Member] | Downstream [Member] | United States [Member]
Segment Reporting Information [Line Items]
Total Assets	22,264	21,404
Operating Segments [Member] | Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Total Assets	15,816	14,982
All Other [Member]
Segment Reporting Information [Line Items]
Total Assets	10,753	15,153
All Other [Member] | United States [Member]
Segment Reporting Information [Line Items]
Total Assets	4,852	4,728
All Other [Member] | International [Member]
Segment Reporting Information [Line Items]
Total Assets	$ 5,901	$ 10,425

Operating Segments and Geogra85

Operating Segments and Geographic Data (Details 2) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Sales and other operating revenues	[1]	$ 110,215	$ 129,925	$ 200,494
Upstream [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		33,145	39,827	69,825
Upstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		10,365	12,748	22,910
Upstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		22,780	27,079	46,915
Downstream [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		94,743	111,629	177,846
Downstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		44,717	52,872	78,606
Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		50,026	58,757	99,240
Corporate and Other [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		1,142	1,555	1,758
Corporate and Other [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		1,105	1,513	1,727
Corporate and Other [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		37	42	31
Operating Segments [Member] | Upstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		3,148	4,117	7,455
Operating Segments [Member] | Upstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		13,262	15,587	23,808
Operating Segments [Member] | Downstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		40,366	48,420	73,942
Operating Segments [Member] | Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		46,388	54,296	86,848
Operating Segments [Member] | Corporate and Other [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		145	141	252
Operating Segments [Member] | Corporate and Other [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		1	5	3
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		(18,815)	(23,086)	(48,935)
Intersegment Eliminations [Member] | Upstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		7,217	8,631	15,455
Intersegment Eliminations [Member] | Upstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		9,518	11,492	23,107
Intersegment Eliminations [Member] | Downstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		16	26	31
Intersegment Eliminations [Member] | Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		1,068	1,528	8,839
Intersegment Eliminations [Member] | Corporate and Other [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		960	1,372	1,475
Intersegment Eliminations [Member] | Corporate and Other [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		36	37	28
Excise and Similar Taxes [Member] | Downstream [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		4,335	4,426	4,633
Excise and Similar Taxes [Member] | Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		2,570	2,933	3,553
All Other [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		129,030	153,011	249,429
All Other [Member] | Total United States [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		56,187	67,133	103,243
All Other [Member] | International [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		$ 72,843	$ 85,878	$ 146,186
[1]	Includes excise, value-added and similar taxes. $6,905; $7,359; $8,186.

Operating Segments and Geogra86

Operating Segments and Geographic Data (Details 3) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	$ (1,729)	$ 132	$ 11,892
Operating Segments [Member] | Upstream [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	(1,006)	(827)	11,260
Operating Segments [Member] | Upstream [Member] | United States [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	(1,172)	(2,041)	2,043
Operating Segments [Member] | Upstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	166	1,214	9,217
Operating Segments [Member] | Downstream [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	987	2,633	1,769
Operating Segments [Member] | Downstream [Member] | United States [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	503	1,320	1,302
Operating Segments [Member] | Downstream [Member] | International [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	484	1,313	467
All Other [Member]
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	$ (1,710)	$ (1,674)	$ (1,137)

Operating Segments and Geogra87

Operating Segments and Geographic Data (Details Textual)	12 Months Ended
	Dec. 31, 2016segment
Segment Reporting [Abstract]
Number of reportable segments (in segments)	2
Number of operating segments (in segments)	2

Investments and Advances (Detai

Investments and Advances (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Investments and Advances	$ 29,789	$ 26,578
Other at or below cost	461	532
Total investments and advances	30,250	27,110
Equity in Earnings	2,661	4,684	$ 7,098
Investments and Advances [Member] | United States [Member]
Schedule of Equity Method Investments [Line Items]
Total investments and advances	7,258	6,863
Investments and Advances [Member] | International [Member]
Schedule of Equity Method Investments [Line Items]
Total investments and advances	22,992	20,247
Equity in Earnings [Member] | United States [Member]
Schedule of Equity Method Investments [Line Items]
Equity in Earnings	802	1,342	1,623
Equity in Earnings [Member] | International [Member]
Schedule of Equity Method Investments [Line Items]
Equity in Earnings	1,859	3,342	5,475
All Other [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	(16)	(18)
Equity in Earnings	(4)	(3)	(4)
Upstream [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	19,153	16,703
Equity in Earnings	1,243	2,218	4,713
Upstream [Member] | Tengizchevroil LLP [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	11,414	8,077
Equity in Earnings	1,380	1,939	4,392
Upstream [Member] | Petropiar [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	977	679
Equity in Earnings	326	180	26
Upstream [Member] | Caspian Pipeline Consortium [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	1,245	1,342
Equity in Earnings	145	162	191
Upstream [Member] | Petroboscan [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	982	1,163
Equity in Earnings	(133)	219	186
Upstream [Member] | Angola LNG Limited [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	2,744	3,284
Equity in Earnings	(282)	(417)	(311)
Upstream [Member] | Other [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	1,791	2,158
Equity in Earnings	(193)	135	229
Downstream [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	10,652	9,893
Equity in Earnings	1,422	2,469	2,389
Downstream [Member] | GS Caltex Corporation [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	3,767	3,620
Equity in Earnings	373	824	420
Downstream [Member] | Chevron Phillips Chemical Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	5,767	5,196
Equity in Earnings	840	1,367	1,606
Downstream [Member] | Caltex Australia Limited [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	0	0
Equity in Earnings	0	92	183
Downstream [Member] | Other [Member]
Schedule of Equity Method Investments [Line Items]
Investments and Advances	1,118	1,077
Equity in Earnings	$ 209	$ 186	$ 180

Investments and Advances (Det89

Investments and Advances (Details 1) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Affiliates [Member]
Schedule of Investments [Line Items]
Total revenues	$ 59,253	$ 71,389	$ 123,003
Income before income tax expense	6,587	13,129	20,609
Net income attributable to affiliates	5,127	10,649	14,758
Current assets	33,406	27,162	35,662
Noncurrent assets	75,258	71,650	70,817
Current liabilities	24,793	20,559	25,308
Noncurrent liabilities	22,671	18,560	17,983
Total net equity	61,200	59,693	63,188
Chevron [Member]
Schedule of Investments [Line Items]
Total revenues	27,787	33,492	58,937
Income before income tax expense	3,670	6,279	9,968
Net income attributable to affiliates	2,876	4,691	7,237
Current assets	13,743	10,657	13,465
Noncurrent assets	28,854	26,607	26,053
Current liabilities	8,996	7,351	9,588
Noncurrent liabilities	4,255	3,909	4,211
Total net equity	$ 29,346	$ 26,004	$ 25,719

Investments and Advances (Det90

Investments and Advances (Details 2) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Variable Interest Entity [Line Items]
Percentage of affiliate by summarized financial information		100.00%
Investments and advances	$ 29,789	$ 26,578
Carrying amount of long-term debt	32,490	27,071
Related Party Transaction, Other Revenues from Transactions with Related Party	5,786	4,850	$ 10,404
Purchased crude oil and products	59,321	69,751	119,671
Accounts and notes receivable due from affiliated companies	676	399
Accounts payable due to affiliated companies	383	286
Chevron's loan to affiliates	3,535	410	874
Affiliated Entity [Member]
Variable Interest Entity [Line Items]
Purchased crude oil and products	$ 3,468	$ 4,240	$ 6,735
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	$ 140
Long term loans of Caspian Pipeline Consortium included in investments and advances	$ 2,000
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	$ 150
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	$ 921
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	$ 120
Carrying amount of long-term debt	$ 626
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%
Tengizchevroil LLP [Member]
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage	50.00%

Properties, Plant and Equipme91

Properties, Plant and Equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Properties, Plant and Equipment
Gross Investment at Cost	$ 336,077	$ 340,277	$ 327,289
Net Investment	182,186	188,396	183,173
Additions at Cost	17,623	28,002	36,332
Depreciation Expense	19,457	21,037	16,793
United States [Member]
Properties, Plant and Equipment
Gross Investment at Cost	111,987	122,550	125,163
Net Investment	52,541	56,791	59,960
Additions at Cost	5,158	7,639	10,857
Depreciation Expense	7,860	9,862	6,693
International [Member]
Properties, Plant and Equipment
Gross Investment at Cost	224,090	217,727	202,126
Net Investment	129,645	131,605	123,213
Additions at Cost	12,465	20,363	25,475
Depreciation Expense	11,597	11,175	10,100
Upstream [Member]
Properties, Plant and Equipment
Gross Investment at Cost	298,486	302,243	289,487
Net Investment	165,212	170,584	164,790
Additions at Cost	16,516	26,579	34,608
Depreciation Expense	17,823	19,348	14,815
Upstream [Member] | United States [Member]
Properties, Plant and Equipment
Gross Investment at Cost	83,929	93,848	96,850
Net Investment	39,710	43,125	45,864
Additions at Cost	4,432	6,586	9,688
Depreciation Expense	6,576	8,545	5,127
Upstream [Member] | International [Member]
Properties, Plant and Equipment
Gross Investment at Cost	214,557	208,395	192,637
Net Investment	125,502	127,459	118,926
Additions at Cost	12,084	19,993	24,920
Depreciation Expense	11,247	10,803	9,688
Downstream [Member]
Properties, Plant and Equipment
Gross Investment at Cost	32,145	32,379	31,974
Net Investment	14,290	14,897	15,238
Additions at Cost	903	1,061	1,118
Depreciation Expense	1,288	1,233	1,282
Downstream [Member] | United States [Member]
Properties, Plant and Equipment
Gross Investment at Cost	22,795	23,202	22,640
Net Investment	10,196	10,807	11,019
Additions at Cost	528	696	588
Depreciation Expense	956	878	886
Downstream [Member] | International [Member]
Properties, Plant and Equipment
Gross Investment at Cost	9,350	9,177	9,334
Net Investment	4,094	4,090	4,219
Additions at Cost	375	365	530
Depreciation Expense	332	355	396
All Other Segments [Member]
Properties, Plant and Equipment
Gross Investment at Cost	5,446	5,655	5,828
Net Investment	2,684	2,915	3,145
Additions at Cost	204	362	606
Depreciation Expense	346	456	696
All Other Segments [Member] | United States [Member]
Properties, Plant and Equipment
Gross Investment at Cost	5,263	5,500	5,673
Net Investment	2,635	2,859	3,077
Additions at Cost	198	357	581
Depreciation Expense	328	439	680
All Other Segments [Member] | International [Member]
Properties, Plant and Equipment
Gross Investment at Cost	183	155	155
Net Investment	49	56	68
Additions at Cost	6	5	25
Depreciation Expense	$ 18	$ 17	$ 16

Properties, Plant and Equipme92

Properties, Plant and Equipment (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 182,186	$ 188,396	$ 183,173
Dry hole expense related to prior years expenditures, net	175	1,573	371
Accretion expense	749	715	882
Impairment charges	3,186	4,066	1,274
Australia [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	53,962	49,205	41,012
Nigeria [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 17,922	$ 18,773	$ 19,214

Litigation (Details)

Litigation (Details) $ in Millions

Jul. 22, 2016USD ($)

Aug. 03, 2012USD ($)

Feb. 14, 2011USD ($)

Sep. 30, 2010USD ($)

Aug. 31, 2010

Dec. 31, 2016LegalMatterbreach

Dec. 31, 1998USD ($)

Dec. 31, 1993breach

Nov. 13, 2013USD ($)

Jul. 02, 2013USD ($)

Nov. 06, 2012

Jan. 03, 2012

Dec. 31, 2008USD ($)

Loss Contingencies [Line Items]

Number of contract breaches (in contracts) | breach

7

MTBE [Member] | Pending Litigation [Member]

Loss Contingencies [Line Items]

Pending lawsuits and claims (in number of claims) | LegalMatter

6

Ecuador Litigation [Member]

Loss Contingencies [Line Items]

Pending lawsuits and claims (in number of claims) | LegalMatter

9

Approved court-appointed liquadator's report damages for total judgment

$ 96

Number of contract breaches (in contracts) | breach

7

Gain related to litigation settlement

$ 113

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

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

Proposed additional payment for plaintiff attorney fees as percentage of judgment

0.10%

Approved court-appointed liquadator's report damages for total judgment

$ 19,100

Amount to be paid via third party

$ 96

Percentage of payments withheld by third parties due to freeze order (percent)

40.00%

Percentage of funds wIthheld by banks due to freeze order (percent)

40.00%

Ecuador Litigation [Member] | Pending Litigation [Member] | Minimum [Member]

Loss Contingencies [Line Items]

Loss Contingency, Estimate of Possible Loss

$ 16,000

Approximate Unjust Enrichment

5,000

Ecuador Litigation [Member] | Pending Litigation [Member] | Maximum [Member]

Loss Contingencies [Line Items]

Loss Contingency, Estimate of Possible Loss

76,000

Approximate Unjust Enrichment

$ 38,000

Ecuador Litigation [Member] | Declaratory 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, 2016	Dec. 31, 2015	Dec. 31, 2014
U.S. federal
Current	$ (623)	$ (817)	$ 748
Deferred	(1,558)	(580)	1,330
State and local
Current	(15)	(187)	336
Deferred	(121)	(109)	36
Total United States	(2,317)	(1,693)	2,450
International
Current	2,744	2,997	9,235
Deferred	(2,156)	(1,172)	207
Total International	588	1,825	9,442
Total income tax expense (benefit)	$ (1,729)	$ 132	$ 11,892

Taxes (Details 1)

Taxes (Details 1) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income (loss) before income taxes
United States		$ (4,317)	$ (2,877)	$ 6,296
International		2,157	7,719	24,906
Income (Loss) Before Income Tax Expense		(2,160)	4,842	31,202
Effective Income Tax Rate Reconciliation, Amount [Abstract]
Theoretical tax (at U.S. statutory rate of 35%)		(756)	1,695	10,921
Equity affiliate accounting effect		(704)	(1,286)	(2,039)
Effect of income taxes from international operations		608	72	2,708
State and local taxes on income, net of U.S. federal income tax benefit		(44)	(74)	234
Prior year tax adjustments, claims and settlements		(349)	84	(76)
Tax credits		(188)	(35)	(68)
Other		(296)	(324)	212
Total income tax expense (benefit)		$ (1,729)	$ 132	$ 11,892
Effective income tax rate		80.00%	2.70%	38.10%
U.S. statutory tax rate		35.00%
Deferred tax liabilities
Properties, plant and equipment		$ 25,180	$ 27,044
Investments and other		5,222	3,743
Total deferred tax liabilities		30,402	30,787
Deferred tax assets
Foreign tax credits		(10,976)	(10,534)
Abandonment/environmental reserves		(6,251)	(6,880)
Employee benefits		(4,392)	(4,801)
Deferred credits		(1,950)	(1,810)
Tax loss carryforwards		(6,030)	(2,748)
Other accrued liabilities		(510)	(525)
Inventory		(374)	(120)
Miscellaneous		(3,121)	(2,525)
Total deferred tax assets		(33,604)	(29,943)
Deferred tax assets valuation allowance		16,069	15,412
Total deferred taxes, net		12,867	16,256
Classification of deferred taxes
Deferred charges and other assets		(4,649)	(3,909)
Noncurrent deferred income taxes	[1]	17,516	20,165
Total deferred taxes, net		$ 12,867	$ 16,256
[1]	2015 adjusted to conform to ASU 2015-17. Refer to Note 18, "Income Taxes" beginning on page FS-45.

Taxes (Details 2)

Taxes (Details 2) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Changes to company's unrecognized tax benefits
Balance at January 1		$ 3,042	$ 3,552	$ 3,848
Foreign currency effects		1	(27)	(25)
Additions based on tax positions taken in current year		245	154	354
Additions/reductions resulting from current-year asset acquisitions/sales		0	0	(22)
Additions for tax positions taken in prior years		181	218	37
Reductions for tax positions taken in prior years		(390)	(678)	(561)
Settlements with taxing authorities in current year		(36)	(5)	(50)
Reductions as a result of a lapse of the applicable statute of limitations		(12)	(172)	(29)
Balance at December 31		3,031	3,042	3,552
Income Tax Authority [Line Items]
Excise and similar taxes on products and merchandise		6,905	7,359	8,186
Import duties and other levies	[1]	11,668	12,030	12,540
Total taxes other than on income		11,668	12,030	12,540
United States
Income Tax Authority [Line Items]
Excise and similar taxes on products and merchandise		4,335	4,426	4,633
Import duties and other levies		9	4	6
Property and other miscellaneous taxes		1,680	1,367	1,002
Payroll taxes		252	270	273
Taxes on production		159	157	349
Total taxes other than on income		6,435	6,224	6,263
International
Income Tax Authority [Line Items]
Excise and similar taxes on products and merchandise		2,570	2,933	3,553
Import duties and other levies		33	40	45
Property and other miscellaneous taxes		2,379	2,548	2,277
Payroll taxes		145	161	172
Taxes on production		106	124	230
Total taxes other than on income		$ 5,233	$ 5,806	$ 6,277
[1]	Includes excise, value-added and similar taxes. $6,905; $7,359; $8,186.

Taxes (Details Textual)

Taxes (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Decrease in income tax expense	$ 1,861
Income tax expense (benefit)	$ (1,729)	$ 132	$ 11,892
Effective tax rate	80.00%	2.70%	38.10%
Deferred tax asset, increase	$ 3,700
Loss carry forward	16,538
Tax credit carryforward	1,423
Carry forward amount of foreign tax credit with expiration dates	10,976	$ 10,534
Undistributed earnings of international consolidated subsidiaries and affiliates for which no deferred income tax provision has been made for future remittances	$ 46,400
Percentage of impact of unrecognized tax benefits on effective tax rate if subsequently recognized	74.00%
Unrecognized tax benefits	$ 3,031	3,042	$ 3,552	$ 3,848
Income tax accruals for anticipated interest and penalty obligations	424	399
Income tax benefit expense associated with interest and penalties	$ 38	195	$ 4
New Accounting Pronouncement, Early Adoption, Effect [Member] | Prepaid Expenses and Other Current Assets [Member]
New Accounting Pronouncement, Early Adoption [Line Items]
Deferred income tax assets, net		(917)
New Accounting Pronouncement, Early Adoption, Effect [Member] | Deferred charges and other assets [Member]
New Accounting Pronouncement, Early Adoption [Line Items]
Deferred income tax assets, net		(603)
New Accounting Pronouncement, Early Adoption, Effect [Member] | Accrued Income Taxes Current [Member]
New Accounting Pronouncement, Early Adoption [Line Items]
Deferred income tax liabilities, net		(996)
New Accounting Pronouncement, Early Adoption, Effect [Member] | Deferred Tax Liabilities, Net, Noncurrent [Member]
New Accounting Pronouncement, Early Adoption [Line Items]
Deferred income tax liabilities, net		$ (524)

Short-Term Debt (Details)

Short-Term Debt (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015
Short term borrowings
Commercial Paper		$ 10,410	$ 8,252
Notes payable to banks and others with originating terms of one year or less		50	20
Current maturities of long-term debt		6,253	1,486
Current maturities of long-term capital leases		14	17
Redeemable long term obligations - Long-term debt		3,113	3,152
Redeemable long term obligations - Capital leases		0	0
Subtotal		19,840	12,927
Reclassified to long-term debt		(9,000)	(8,000)
Total short-term debt	[1]	$ 10,840	$ 4,927
[1]	2015 adjusted to conform to ASU 2015-03. Refer to Note 5, "New Accounting Standards" beginning on page FS-32.

Short-Term Debt (Details Textua

Short-Term Debt (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Weighted-average interest rates of commercial paper	0.74%	0.26%
Committed credit facilities	$ 9,000
Debt instrument, term	364 days
Reclassified to long-term debt	$ 9,000	$ 8,000
Expiring in December 2017 [Member]
Debt Instrument [Line Items]
Committed credit facilities	6,900
Expiring in December 2020 [Member]
Debt Instrument [Line Items]
Committed credit facilities	$ 2,100
Debt instrument, term	5 years

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	May 31, 2016
Debt Instrument [Line Items]
Long-term debt, excluding current maturities	[1]	$ 35,193	$ 33,542
Long-term debt instruments		32,490	27,071
Unamortized discounts and debt issuance costs		44	43
Debt due within one year		(6,256)	(1,487)
Unamortized discounts and debt issuance costs, due within one year		(3)	(1)
Reclassified from short-term debt		9,000	8,000
Total long-term debt		35,234	33,584
Unamortized discounts and debt issuance costs, excluding current maturities		41	42
Long-term debt maturing 2017		6,256
Long-term debt maturing 2018		6,722
Long-term debt maturing 2019		4,000
Long-term debt maturing 2020		4,054
Long-term debt maturing 2021		2,054
Long-term debt maturing after 2021		9,404
Notes Payable [Member] | 3.191% notes due 2023 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		2,250	2,250
Unamortized discounts and debt issuance costs		$ 4	4
Interest rate		3.191%
Notes Payable [Member] | 2.954% notes due 2026 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 2,250	0
Unamortized discounts and debt issuance costs		$ 6	0
Interest rate		2.954%
Notes Payable [Member] | Floating rate notes due 2017 (1.091%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 2,050	2,050
Unamortized discounts and debt issuance costs		$ 1	2
Interest rate		1.091%
Notes Payable [Member] | 1.104% notes due 2017 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 2,000	2,000
Unamortized discounts and debt issuance costs		$ 1	2
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
Unamortized discounts and debt issuance costs		$ 1	2
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
Unamortized discounts and debt issuance costs		$ 5	5
Interest rate		2.355%
Notes Payable [Member] | 1.365% notes due 2018 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,750	1,750
Unamortized discounts and debt issuance costs		$ 1	2
Interest rate		1.365%
Notes Payable [Member] | 1.961% notes due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,750	1,750
Unamortized discounts and debt issuance costs		$ 2	2
Interest rate		1.961%
Notes Payable [Member] | Floating Rate Notes due 2018 (1.310%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,650	800
Unamortized discounts and debt issuance costs		$ 2	1
Interest rate		1.31%
Notes Payable [Member] | 4.95% notes due 2019 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,500	1,500
Unamortized discounts and debt issuance costs		$ 2	2
Interest rate		4.95%
Notes Payable [Member] | 1.561% notes due 2019 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,350	0
Unamortized discounts and debt issuance costs		$ 2	0
Interest rate		1.561%
Notes Payable [Member] | 2.100% notes due 2021 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,350	0
Unamortized discounts and debt issuance costs		$ 2	0
Interest rate		2.10%
Notes Payable [Member] | 1.790% notes due 2018 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,250	1,250
Unamortized discounts and debt issuance costs		$ 1	2
Interest rate		1.79%
Notes Payable [Member] | 2.419% notes due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,250	1,250
Unamortized discounts and debt issuance costs		$ 2	2
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
Unamortized discounts and debt issuance costs		$ 0	2
Interest rate		1.345%
Notes Payable [Member] | 1.344% notes due 2017 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,000	1,000
Unamortized discounts and debt issuance costs		$ 1	1
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
Unamortized discounts and debt issuance costs		$ 1	2
Interest rate		2.427%
Notes Payable [Member] | 2.193% notes due 2019 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 750	750
Unamortized discounts and debt issuance costs		$ 1	1
Interest rate		2.193%
Notes Payable [Member] | 2.566% notes due 2023 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 750	0
Unamortized discounts and debt issuance costs		$ 1	0
Interest rate		2.566%
Notes Payable [Member] | 3.326% notes due 2025 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 750	750
Unamortized discounts and debt issuance costs		$ 2	2
Interest rate		3.326%
Notes Payable [Member] | 2.411% notes due 2022 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 700	700
Unamortized discounts and debt issuance costs		$ 1	1
Interest rate		2.411%
Notes Payable [Member] | Floating Rate Notes due 2021 (1.599%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 650	400
Unamortized discounts and debt issuance costs		$ 1	1
Interest rate		1.599%
Notes Payable [Member] | Floating rate notes due 2019 (1.316%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 400	400
Unamortized discounts and debt issuance costs		$ 1	2
Interest rate		1.316%
Notes Payable [Member] | Floating rate notes due 2022 (1.472%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 350	350
Unamortized discounts and debt issuance costs		$ 0	1
Interest rate		1.472%
Notes Payable [Member] | 0.889% notes due 2016 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 0	750
Unamortized discounts and debt issuance costs		$ 0	0
Interest rate		0.889%
Notes Payable [Member] | Floating rate notes due 2016 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 0	700
Unamortized discounts and debt issuance costs		0	1
Debentures [Member] | Amortizing Bank Loan due 2018 (1.527%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments		178	110
Unamortized discounts and debt issuance costs		$ 0	0
Interest rate		1.527%
Debentures [Member] | 8.625% debentures due 2032 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 147	147
Unamortized discounts and debt issuance costs		$ 1	1
Interest rate		8.625%
Debentures [Member] | 8.625 % debentures due 2031 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 108	108
Unamortized discounts and debt issuance costs		$ 1	1
Interest rate		8.625%
Debentures [Member] | 8 % debentures due 2032 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 75	74
Unamortized discounts and debt issuance costs		$ 1	1
Interest rate		8.00%
Debentures [Member] | 9.75 % debentures due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 54	54
Unamortized discounts and debt issuance costs		$ 0	0
Interest rate		9.75%
Debentures [Member] | 8.875 % debentures due 2021 [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 40	40
Unamortized discounts and debt issuance costs		$ 0	0
Interest rate		8.875%
Medium-term Notes [Member] | Medium-term notes, maturing from 2021 to 2038 (6.133%) [Member]
Debt Instrument [Line Items]
Long-term debt instruments		$ 38	38
Unamortized discounts and debt issuance costs		$ 0	$ 0
Interest rate		6.133%
Corporate Bond Securities [Member]
Debt Instrument [Line Items]
Debt issued				$ 6,800
[1]	2015 adjusted to conform to ASU 2015-03. Refer to Note 5, "New Accounting Standards" beginning on page FS-32.

Accounting for Suspended Exp101

Accounting for Suspended Exploratory Wells (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2016USD ($)Project	Dec. 31, 2015USD ($)Project	Dec. 31, 2014USD ($)Project
Changes in company's suspended exploratory well costs
Beginning balance at January 1	$ 3,312	$ 4,195	$ 3,245
Additions to capitalized exploratory well costs pending the determination of proved reserves	465	869	1,591
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	(119)	(164)	(298)
Capitalized exploratory well costs charged to expense	(118)	(1,397)	(312)
Other reductions	0	(191)	(31)
Ending balance at December 31	3,540	3,312	4,195
Aging of capitalized well costs and number of project
Exploratory well costs capitalized for a period of one year or less				$ 445	$ 489	$ 1,522
Exploratory well costs capitalized for a period greater than one year				3,095	2,823	2,673
Balance at December 31	$ 3,312	$ 4,195	$ 3,245	$ 3,540	$ 3,312	$ 4,195
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project				35	39	51

Accounting for Suspended Exp102

Accounting for Suspended Exploratory Wells (Details 1) $ in Millions	Dec. 31, 2016USD ($)WellProject	Dec. 31, 2015USD ($)Project	Dec. 31, 2014USD ($)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	$ 3,095	$ 2,823	$ 2,673
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well	160
Number of projects (in projects) | Project	35	39	51
1998–2005 [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	$ 311
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well	29
2006–2010 [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	$ 684
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well	40
2011–2015 [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	$ 2,100
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well	91
2003-2008 [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	$ 212
Number of projects (in projects) | Project	4
2009–2012 [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	$ 437
Number of projects (in projects) | Project	8
2013–2016 [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	$ 2,446
Number of projects (in projects) | Project	23

Accounting for Suspended Exp103

Accounting for Suspended Exploratory Wells (Details Textual) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)WellProject	Dec. 31, 2015USD ($)Project	Dec. 31, 2014USD ($)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 | $	$ 3,095	$ 2,823	$ 2,673
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project	35	39	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	160
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 | $	$ 1,939
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project	15
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 | $	$ 1,156
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project	20
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 (in projects) | 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 | $	$ 107
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project	2
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 | $	$ 816
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | 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 (in projects) | Project	9
Capitalized exploratory well costs that are approved and construction in progress | $	$ 43

Stock Options and Other Shar104

Stock Options and Other Share-Based Compensation (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Stock Option
Expected term in years	6 years 3 months 18 days	6 years 1 month 6 days	6 years
Volatility	21.70%	21.90%	30.30%
Risk-free interest rate based on zero coupon U.S. treasury note	1.60%	1.40%	1.90%
Dividend yield	4.50%	3.60%	3.30%
Weighted-average fair value per option granted (in dollars per share)	$ 9.53	$ 13.89	$ 25.86
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Outstanding, beginning balance (in shares)	94,292
Shares, Granted (in shares)	30,913
Shares, Exercised (in shares)	(8,589)
Shares, Forfeited (in shares)	(4,341)
Outstanding, ending balance (in shares)	112,275	94,292
Shares, Exercisable at December 31, 2015 (in shares)	71,153
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, 2015 (in dollars per share)	$ 96.67
Weighted-Average Exercise Price, Granted (in dollars per share)	83.31
Weighted-Average Exercise Price, Exercised (in dollars per share)	75.57
Weighted-Average Exercise Price, Forfeited (in dollars per share)	86.81
Weighted-Average Exercise Price, Outstanding at December 31, 2016 (in dollars per share)	94.99	$ 96.67
Weighted-Average Exercise Price, Exercisable at December 31, 2016 (in dollars per share)	$ 97.32
Average Remaining Contractual Term, Outstanding at December 31, 2016 (in years)	6 years 1 month 17 days
Average Remaining Contractual Term, Exercisable at December 31, 2016 (in years)	4 years 7 months 28 days
Aggregate Intrinsic Value, Outstanding at December 31, 2016	$ 2,550
Aggregate Intrinsic Value, Exercisable at December 31, 2016	$ 1,450

Stock Options and Other Shar105

Stock Options and Other Share-Based Compensation (Details 1) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense for stock options	$ 271	$ 312	$ 287
After tax compensation expense for stock options	176	203	186
Compensation expense for stock appreciation rights restricted stock performance units and restricted stock units	371	32	71
Compensation expense for stock appreciation rights, restricted stock, performance units and restricted stock units, after tax	241	21	46
Cash received in payment for option exercises	647	195	527
Tax benefits realized for the tax deductions from option exercises	21	17	54
Cash paid to settle performance units and stock appreciation rights	$ 82	104	204
Maximum number of share that may be issued under LTIP (in shares)	859,746
Total intrinsic value options exercised	$ 240	$ 120	$ 398
Total before-tax compensation cost related to nonvested share-based compensation arrangements	$ 169
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)	2,393,428	2,192,937
Number of LTIP performance units granted (in shares)	1,019,900
Number of LTIP performance units vested outstanding (in shares)	718,472
Number of LTIP performance units forfeited (in shares)	100,937
Fair value of the liability recorded for LTIP performance units outstanding	$ 381
Equivalent shares granted under various LTIP and former Texaco and Unocal programs for outstanding stock appreciation rights and other awards	5,400,000
Liability recorded for Equivalent shares granted under various LTIP and former Texaco and Unocal programs for outstanding stock appreciation rights and other awards	$ 125
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)	87,000,000
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 and Restricted Stock Units (RSUs) [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
Performance Shares and Restricted Stock Units (RSUs) [Member] | Chevron Long-Term Incentive Plan (LTIP), 2017 Issuance [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award contractual term (in years)	3 years
Restricted Stock Units (RSUs) [Member] | Chevron Long-Term Incentive Plan (LTIP), 2017 Issuance [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award contractual term (in years)	5 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
Stock Options and Stock Appreciation Rights [Member] | Chevron Long-Term Incentive Plan (LTIP), 2017 Issuance [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, 2016	Dec. 31, 2015	Dec. 31, 2014
U.S. [Member]
Change in Benefit Obligation
Benefit obligation at January 1	$ 13,563	$ 14,250
Service cost	494	538	$ 450
Interest cost	377	502	494
Plan participants' contributions	0	0
Plan amendments	0	0
Actuarial (gain) loss	903	(345)
Foreign currency exchange rate changes	0	0
Benefits paid	(2,066)	(1,382)
Curtailment	0	0
Benefit obligation at December 31	13,271	13,563	14,250
Change in Plan Assets
Fair value of plan assets at January 1	10,274	11,090
Actual return on plan assets	936	(75)
Foreign currency exchange rate changes	0	0
Employer contributions	406	641
Plan participants' contributions	0	0
Benefits paid	(2,066)	(1,382)
Fair value of plan assets at December 31	9,550	10,274	11,090
Funded status at December 31	(3,721)	(3,289)
International [Member]
Change in Benefit Obligation
Benefit obligation at January 1	5,336	5,767
Service cost	159	185	190
Interest cost	261	277	340
Plan participants' contributions	5	6
Plan amendments	0	(6)
Actuarial (gain) loss	426	(309)
Foreign currency exchange rate changes	(524)	(326)
Benefits paid	(494)	(241)
Curtailment	0	(17)
Benefit obligation at December 31	5,169	5,336	5,767
Change in Plan Assets
Fair value of plan assets at January 1	4,109	4,244
Actual return on plan assets	642	112
Foreign currency exchange rate changes	(552)	(239)
Employer contributions	464	227
Plan participants' contributions	5	6
Benefits paid	(494)	(241)
Fair value of plan assets at December 31	4,174	4,109	4,244
Funded status at December 31	(995)	(1,227)
Other Benefits [Member]
Change in Benefit Obligation
Benefit obligation at January 1	3,324	3,660
Service cost	60	72	50
Interest cost	128	151	148
Plan participants' contributions	148	148
Plan amendments	(345)	0
Actuarial (gain) loss	(437)	(326)
Foreign currency exchange rate changes	8	(37)
Benefits paid	(337)	(344)
Curtailment	0	0
Benefit obligation at December 31	2,549	3,324	3,660
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	189	196
Plan participants' contributions	148	148
Benefits paid	(337)	(344)
Fair value of plan assets at December 31	0	0	$ 0
Funded status at December 31	$ (2,549)	$ (3,324)

Employee Benefit Plans (Deta107

Employee Benefit Plans (Details 1) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Consolidated Balance Sheet for pension and other postretirement benefit plans
Noncurrent employee benefit plans	$ (7,216)	$ (7,935)
U.S. [Member]
Consolidated Balance Sheet for pension and other postretirement benefit plans
Deferred charges and other assets	16	13
Accrued liabilities	(222)	(153)
Noncurrent employee benefit plans	(3,515)	(3,149)
Net amount recognized at December 31	(3,721)	(3,289)
International [Member]
Consolidated Balance Sheet for pension and other postretirement benefit plans
Deferred charges and other assets	199	333
Accrued liabilities	(75)	(77)
Noncurrent employee benefit plans	(1,119)	(1,483)
Net amount recognized at December 31	(995)	(1,227)
Other Benefits [Member]
Consolidated Balance Sheet for pension and other postretirement benefit plans
Deferred charges and other assets	0	0
Accrued liabilities	(163)	(191)
Noncurrent employee benefit plans	(2,386)	(3,133)
Net amount recognized at December 31	$ (2,549)	$ (3,324)

Employee Benefit Plans (Deta108

Employee Benefit Plans (Details 2) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Before tax basis amount in accumulated other comprehensive loss.
Total recognized at December 31	$ 5,511	$ 6,478
U.S. [Member]
Before tax basis amount in accumulated other comprehensive loss.
Net actuarial loss	4,653	4,809
Prior service (credit) costs	4	(5)
Total recognized at December 31	4,657	4,804
International [Member]
Before tax basis amount in accumulated other comprehensive loss.
Net actuarial loss	1,145	1,143
Prior service (credit) costs	106	120
Total recognized at December 31	1,251	1,263
Other Benefits [Member]
Before tax basis amount in accumulated other comprehensive loss.
Net actuarial loss	(82)	367
Prior service (credit) costs	(315)	44
Total recognized at December 31	$ (397)	$ 411

Employee Benefit Plans (Deta109

Employee Benefit Plans (Details 3) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
U.S. [Member]
Pension Plans With Accumulated Benefit Obligation in Excess of Plan Assets
Projected benefit obligations	$ 13,208	$ 13,500
Accumulated benefit obligations	11,891	11,969
Fair value of plan assets	9,471	10,198
International [Member]
Pension Plans With Accumulated Benefit Obligation in Excess of Plan Assets
Projected benefit obligations	1,449	1,623
Accumulated benefit obligations	1,258	1,357
Fair value of plan assets	$ 287	$ 207

Employee Benefit Plans (Deta110

Employee Benefit Plans (Details 4) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Changes Recognized in Comprehensive Income
Prior service (credits) costs during period	$ (345)	$ (6)	$ 6
Amortization of prior service (costs) credits	(19)	(30)	(26)
U.S. [Member]
Net Periodic Benefit Cost
Service cost	494	538	450
Interest cost	377	502	494
Expected return on plan assets	(723)	(783)	(788)
Amortization of prior service costs (credits)	(9)	(8)	(9)
Recognized actuarial losses	335	356	209
Settlement losses	511	320	237
Curtailment losses (gains)	0	0	0
Total net periodic benefit cost	985	925	593
Changes Recognized in Comprehensive Income
Net actuarial (gain) loss during period	690	513	2,233
Amortization of actuarial loss	(846)	(676)	(446)
Prior service (credits) costs during period	0	0	0
Amortization of prior service (costs) credits	9	8	9
Total changes recognized in other comprehensive income	(147)	(155)	1,796
Recognized in Net Periodic Benefit Cost and Other Comprehensive Income	838	770	2,389
International [Member]
Net Periodic Benefit Cost
Service cost	159	185	190
Interest cost	261	277	340
Expected return on plan assets	(243)	(262)	(298)
Amortization of prior service costs (credits)	14	22	21
Recognized actuarial losses	47	78	96
Settlement losses	6	6	208
Curtailment losses (gains)	0	(14)	0
Total net periodic benefit cost	244	292	557
Changes Recognized in Comprehensive Income
Net actuarial (gain) loss during period	55	(260)	(17)
Amortization of actuarial loss	(53)	(84)	(304)
Prior service (credits) costs during period	0	(6)	4
Amortization of prior service (costs) credits	(14)	(24)	(21)
Total changes recognized in other comprehensive income	(12)	(374)	(338)
Recognized in Net Periodic Benefit Cost and Other Comprehensive Income	232	(82)	219
Other Benefits [Member]
Net Periodic Benefit Cost
Service cost	60	72	50
Interest cost	128	151	148
Expected return on plan assets	0	0	0
Amortization of prior service costs (credits)	14	14	14
Recognized actuarial losses	19	34	7
Settlement losses	0	0	0
Curtailment losses (gains)	0	0	0
Total net periodic benefit cost	221	271	219
Changes Recognized in Comprehensive Income
Net actuarial (gain) loss during period	(430)	(362)	514
Amortization of actuarial loss	(19)	(34)	(7)
Prior service (credits) costs during period	(345)	0	2
Amortization of prior service (costs) credits	(14)	(14)	(14)
Total changes recognized in other comprehensive income	(808)	(410)	495
Recognized in Net Periodic Benefit Cost and Other Comprehensive Income	$ (587)	$ (139)	$ 714

Employee Benefit Plans (Deta111

Employee Benefit Plans (Details 5) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Effects of change in the assumed health care cost-trend rates
Effect on total service and interest cost components, 1 Percent Increase	$ 17
Effect on total service and interest cost components, 1 Percent Decrease	(15)
Effect on postretirement benefit obligation, 1 Percent Increase	156
Effect on postretirement benefit obligation, 1 Percent Decrease	$ (128)
U.S. [Member]
Assumptions used to determine benefit obligations:
Discount rate	3.90%	4.00%	3.70%
Rate of compensation increase	4.50%	4.50%	4.50%
Assumptions used to determine net periodic benefit cost:
Discount rate for service cost	4.40%	3.70%	4.30%
Discount rate for interest cost	3.00%	3.70%	4.30%
Expected return on plan assets	7.25%	7.50%	7.50%
Rate of compensation increase	4.50%	4.50%	4.50%
International [Member]
Assumptions used to determine benefit obligations:
Discount rate	4.30%	5.30%	5.00%
Rate of compensation increase	4.50%	4.80%	5.10%
Assumptions used to determine net periodic benefit cost:
Discount rate for service cost	5.30%	5.00%	5.80%
Discount rate for interest cost	5.30%	5.00%	5.80%
Expected return on plan assets	6.30%	6.30%	6.60%
Rate of compensation increase	4.80%	5.10%	5.50%
Other Benefits [Member]
Assumptions used to determine benefit obligations:
Discount rate	4.30%	4.60%	4.30%
Assumptions used to determine net periodic benefit cost:
Discount rate for service cost	4.90%	4.30%	4.90%
Discount rate for interest cost	4.00%	4.30%	4.90%

Employee Benefit Plans (Deta112

Employee Benefit Plans (Details 6) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Fair Value Measurements of Company's Pension Plans
Investment in company's common stock	$ 12	$ 9
U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	9,550	10,274	$ 11,090
U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	3,297	3,306
U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	4,824	5,422
U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,429	1,546
International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	4,174	4,109	$ 4,244
International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,548	1,196
International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	2,274	2,508
International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	352	405
U.S equity [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,217	1,699
U.S equity [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,217	1,699
U.S equity [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	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	0	0
U.S equity [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	565	392
U.S equity [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	564	382
U.S equity [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1	10
U.S equity [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
International Equity Securities [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,832	1,302
International Equity Securities [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,822	1,296
International Equity Securities [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	10	6
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	576	457
International Equity Securities [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	576	435
International Equity Securities [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	22
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	1,132	2,460
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	24	18
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	1,108	2,442
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	0	0
Collective Trusts Mutual Funds Equity [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	196	572
Collective Trusts Mutual Funds Equity [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	8	7
Collective Trusts Mutual Funds Equity [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	188	565
Collective Trusts Mutual Funds Equity [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Government [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	222	257
Government [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	46
Government [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	222	211
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	1,125	1,089
Government [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	51	93
Government [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,074	996
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	1,356	1,654
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	1,356	1,654
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	628	615
Corporate [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	22	33
Corporate [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	587	557
Corporate [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	19	25
Bank Loans [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	118	148
Bank Loans [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Bank Loans [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	107	148
Bank Loans [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	11	0
Bank Loans [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Bank Loans [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Bank Loans [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Bank Loans [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	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	10	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	10	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	0	1
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	0	1
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	1,031	933
Collective Trusts/Mutual Funds [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	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	1,031	933
Collective Trusts/Mutual Funds [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Collective Trusts/Mutual Funds [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	320	269
Collective Trusts/Mutual Funds [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	12
Collective Trusts/Mutual Funds [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	320	257
Collective Trusts/Mutual Funds [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mixed Funds [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mixed Funds [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mixed Funds [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mixed Funds [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mixed Funds [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	72	85
Mixed Funds [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	2	4
Mixed Funds [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	70	81
Mixed Funds [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Real Estate [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,367	1,494
Real Estate [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Real Estate [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Real Estate [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,367	1,494
Real Estate [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	331	378
Real Estate [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Real Estate [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Real Estate [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	331	378
Alternative Investments [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	955
Alternative Investments [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0
Alternative Investments [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	955
Alternative Investments [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0
Alternative Investments [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0
Alternative Investments [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0
Alternative Investments [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0
Alternative Investments [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0
Cash And Cash Equivalents [Member] | U.S. [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	252	253
Cash And Cash Equivalents [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	243	253
Cash And Cash Equivalents [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	9	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	331	232
Cash And Cash Equivalents [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	325	232
Cash And Cash Equivalents [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	6	0
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	67	72
Other [Member] | U.S. [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	(9)	(6)
Other [Member] | U.S. [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	25	26
Other [Member] | U.S. [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	51	52
Other [Member] | International [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	20	19
Other [Member] | International [Member] | Level 1 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	(2)
Other [Member] | International [Member] | Level 2 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	18	19
Other [Member] | International [Member] | Level 3 [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	$ 2	$ 2

Employee Benefit Plans (Deta113

Employee Benefit Plans (Details 7) - Level 3 [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
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	$ 1,951	$ 1,772
Actual Return on Plan Assets:
Assets held at the reporting date	(85)	145
Assets sold during the period	122	23
Purchases, Sales and Settlements	(207)	11
Transfers in and/or out of Level 3	0	0
Ending Balance	1,781	1,951
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	25	22
Actual Return on Plan Assets:
Assets held at the reporting date	1	(3)
Assets sold during the period	0	0
Purchases, Sales and Settlements	(7)	6
Transfers in and/or out of Level 3	0	0
Ending Balance	19	25
Bank Loans [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	0
Actual Return on Plan Assets:
Assets held at the reporting date	0	0
Assets sold during the period	0	0
Purchases, Sales and Settlements	11	0
Transfers in and/or out of Level 3	0	0
Ending Balance	11	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	1,872	1,693
Actual Return on Plan Assets:
Assets held at the reporting date	(85)	149
Assets sold during the period	121	23
Purchases, Sales and Settlements	(210)	7
Transfers in and/or out of Level 3	0	0
Ending Balance	1,698	1,872
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	54	57
Actual Return on Plan Assets:
Assets held at the reporting date	(1)	(1)
Assets sold during the period	1	0
Purchases, Sales and Settlements	(1)	(2)
Transfers in and/or out of Level 3	0	0
Ending Balance	$ 53	$ 54

Employee Benefit Plans (Deta114

Employee Benefit Plans (Details 8) $ in Millions	Dec. 31, 2016USD ($)
U.S. [Member]
Benefit payments, which include estimated future service, are expected to be paid by the company in the next 10years
2,017	$ 1,502
2,018	1,362
2,019	1,310
2,020	1,267
2,021	1,234
2022-2026	5,536
International [Member]
Benefit payments, which include estimated future service, are expected to be paid by the company in the next 10years
2,017	253
2,018	378
2,019	276
2,020	288
2,021	273
2022-2026	1,542
Other Benefits [Member]
Benefit payments, which include estimated future service, are expected to be paid by the company in the next 10years
2,017	163
2,018	163
2,019	164
2,020	164
2,021	164
2022-2026	$ 799

Employee Benefit Plans (Deta115

Employee Benefit Plans (Details Textual) - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
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	$ 5,511	$ 6,478
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	6.90%	7.10%
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	90.00%
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	$ 35	$ 36
Employee Incentive Plan
Charges to expense for cash bonuses	662	690	$ 965
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	4,657	4,804
Accumulated benefit obligations pension plans	$ 11,954	$ 12,032
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	$ 340
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	$ 408
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	$ (5)
Expected Return on Plan Assets:
Estimated long-term rate of return on US pension plan assets	7.25%	7.50%	7.50%
Percentage of US pension plan assets relative to total pension plan assets	69.00%
Plan asset market valuation period, prior to year-end measurement date	3 months
Discount Rate:
Discount rate for pension plans	3.90%	4.00%	3.70%
Cash Contributions and Benefit Payments:
Contributions to employee pension plans	$ 406	$ 641
Estimated contributions to employee pension plans for the next fiscal year	$ 200
U.S. [Member] | Equities [Member]
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation, minimum	30.00%
Pension Plan - Board of Trustees approved asset allocation, maximum	60.00%
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	65.00%
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	15.00%
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	$ 1,251	1,263
Accumulated benefit obligations pension plans	$ 4,676	$ 4,684
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	12 years
Actuarial gain (loss) that will be amortized from Accumulated other comprehensive loss	$ 41
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	10 years
Amortization of prior service (credits) costs during the next year	$ 12
Expected Return on Plan Assets:
Estimated long-term rate of return on US pension plan assets	6.30%	6.30%	6.60%
Discount Rate:
Discount rate for pension plans	4.30%	5.30%	5.00%
Cash Contributions and Benefit Payments:
Contributions to employee pension plans	$ 464	$ 227
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	$ 464
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	70.00%
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	4.10%	4.50%	4.10%
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	$ (397)	$ 411
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	11 years
Actuarial gain (loss) that will be amortized from Accumulated other comprehensive loss	$ (5)
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	11 years
Amortization of prior service (credits) costs during the next year	$ (28)
Discount Rate:
Discount rate for pension plans	4.30%	4.60%	4.30%
Cash Contributions and Benefit Payments:
Contributions to employee pension plans	$ 189	$ 196
Estimated contributions to employee pension plans for the next fiscal year	163
ESIP [Member]
Employee Savings Investment Plan:
Compensation expense	$ 281	$ 316	$ 316

Other Contingencies and Comm116

Other Contingencies and Commitments (Details)	Nov. 07, 2011bbl	Dec. 31, 2016USD ($)Location	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Aug. 27, 2015Employee	Mar. 14, 2012Employee	Dec. 31, 2009USD ($)
Guarantees
Guarantee for payments under terminal use agreements		$ 1,157,000,000
Term of guarantee for payments under terminal use agreement (in years)		5 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 2017		$ 1,527,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2018		1,566,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2019		1,389,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2020		1,071,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2021		968,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2022 and after		2,572,000,000
Total payments under long term unconditional purchase obligations and commitments including throughput and Take-or-Pay agreements		1,300,000,000	$ 1,900,000,000	$ 3,700,000,000
Environmental
Environmental reserve balance		$ 1,467,000,000
Sites with potential remediation activities (in sites) | Location		146
Criminal charges, number of employees charged (employees) | Employee						11
Dismissal of charges, number of employees (employees) | Employee					11
Brazil [Member]
Environmental
Emitted of barrels of oil (barrels) | bbl	2,400
Upstream [Member]
Environmental
Environmental reserve		$ 322,000,000
U.S. Downstream [Member]
Environmental
Environmental reserve		808,000,000
International Downstream [Member]
Environmental
Environmental reserve		51,000,000
Other Businesses [Member]
Environmental
Environmental reserve		2,000,000
Sites with Potential Remediation Activities [Member]
Environmental
Environmental reserve		284,000,000
Environmental Reserve Less Environmental Reserve for Sites with Potential Remediation Activities [Member]
Environmental
Environmental reserve		1,183,000,000
Affiliates [Member]
Guarantees
Guarantee for payments under terminal use agreements		$ 408,000,000
Term of guarantee for payments under terminal use agreement (in years)		11 years
Financing Arrangement [Member]
Guarantees
Guarantee for payments under terminal use agreements		$ 749,000,000

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Company Before Tax Obligation
Balance at January 1	$ 15,642	$ 15,053	$ 14,298
Liabilities incurred	204	51	133
Liabilities settled	(1,658)	(981)	(1,291)
Accretion expense	749	715	882
Revisions in estimated cash flows	(694)	804	1,031
Balance at December 31	14,243	$ 15,642	$ 15,053
Long-term portion of the company's before-tax asset retirement obligations	$ 13,447

Restructuring and Reorganiza118

Restructuring and Reorganization Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Restructuring and Related Activities [Abstract]
Restructuring charges		$ 353
Restructuring Reserve [Roll Forward]
Balance at January 1, 2016	$ 293
Accruals/Adjustments	83
Payments	(316)
Balance at December 31, 2016	$ 60	$ 293

Other Financial Information (De

Other Financial Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Total financing interest and debt costs	$ 753	$ 495	$ 358
Less: Capitalized interest	552	495	358
Interest and debt expense	201	0	0
Research and development expenses	476	601	707
Excess of replacement cost over the carrying value of inventories (LIFO method)	2,942	3,745	8,135
LIFO (losses) / profits on inventory drawdowns included in earnings	(88)	(65)	13
Foreign currency effects	58	769	487
Gains on sale of nonstrategic properties	800	2,300
Gain (loss) for impairments and other assets write-offs	2,900	3,000
Company share of equity affiliates foreign currency effects	1	344	$ 118
Goodwill	4,581	4,588
Downstream [Member]
Segment Reporting Information [Line Items]
Gains on sale of nonstrategic properties	600	1,800
Gain (loss) for impairments and other assets write-offs	110
Upstream [Member]
Segment Reporting Information [Line Items]
Gains on sale of nonstrategic properties	$ 200	$ 500

Schedule II - Valuation and 120

Schedule II - Valuation and Qualifying Accounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Employee Termination Benefits [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at January 1	$ 308	$ 49	$ 14
Additions (reductions) charged to expense	160	342	53
Payments	(357)	(83)	(18)
Balance at December 31	111	308	49
Allowance for Doubtful Accounts [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at January 1	429	194	95
Additions (reductions) charged to expense	76	251	119
Payments	(18)	(16)	(20)
Balance at December 31	487	429	194
Deferred Income Tax Valuation Allowance [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at January 1	15,412	16,292	17,171
Additions to deferred income tax expense	1,810	1,440	1,192
Reduction of deferred income tax expense	(1,153)	(2,320)	(2,071)
Balance at December 31	$ 16,069	$ 15,412	$ 16,292