Chevron (CVX) 10-K 22 Feb 19 2018 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2018	Feb. 11, 2019	Jun. 29, 2018
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, 2018
Amendment Flag	false
Entity Emerging Growth Company	false
Entity Small Business	false
Document Fiscal Year Focus	2,018
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			$ 242.2
Entity Common Stock, Shares Outstanding		1,900,062,760
Entity Shell Company	false

Consolidated Statement of Incom

Consolidated Statement of Income - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenues and Other Income
Sales and other operating revenues	[1]	$ 158,902
Sales and other operating revenues	[1]		$ 134,674	$ 110,215
Income from equity affiliates		6,327	4,438	2,661
Other income		1,110	2,610	1,596
Total Revenues and Other Income		166,339	141,722	114,472
Costs and Other Deductions
Purchased crude oil and products		94,578	75,765	59,321
Operating expenses	[2]	20,544	19,127	19,902
Selling, general and administrative expenses	[2]	3,838	4,110	4,305
Exploration expenses		1,210	864	1,033
Depreciation, depletion and amortization		19,419	19,349	19,457
Taxes other than on income	[1]	4,867	12,331	11,668
Interest and debt expense		748	307	201
Other components of net periodic benefit costs	[2]	560	648	745
Total Costs and Other Deductions		145,764	132,501	116,632
Income (Loss) Before Income Tax Expense		20,575	9,221	(2,160)
Income Tax Expense (Benefit)		5,715	(48)	(1,729)
Net Income (Loss)		14,860	9,269	(431)
Less: Net income attributable to noncontrolling interests		36	74	66
Net Income (Loss) Attributable to Chevron Corporation		$ 14,824	$ 9,195	$ (497)
Net Income (Loss) Attributable to Chevron Corporation
– Basic (in dollars per share)		$ 7.81	$ 4.88	$ (0.27)
– Diluted (in dollars per share)		$ 7.74	$ 4.85	$ (0.27)
[1]	2017 and 2016 include excise, value-added and similar taxes of $7,189 and $6,905, respectively, collected on behalf of third parties. Beginning in 2018, these taxes are netted in "Taxes other than on income" in accordance with Accounting Standards Update (ASU) 2014-09. Refer to Note 25, "Revenue" beginning on page 88.
[2]	2017 and 2016 adjusted to conform to ASU 2017-07. Refer to Note 4, "New Accounting Standards" beginning on page 60.

Consolidated Statement of Inc_2

Consolidated Statement of Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Income Statement [Abstract]
Includes excise, value-added and similar taxes	$ 7,189	$ 6,905

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Statement of Comprehensive Income [Abstract]
Net Income (Loss)	$ 14,860	$ 9,269	$ (431)
Currency translation adjustment
Unrealized net change arising during period	(19)	57	(22)
Unrealized holding gain (loss) on securities
Net gain (loss) arising during period	(5)	(3)	27
Actuarial gain (loss)
Amortization to net income of net actuarial loss and settlements	792	817	918
Actuarial gain (loss) arising during period	85	(571)	(315)
Prior service credits (cost)
Amortization to net income of net prior service costs and curtailments	(13)	(20)	19
Prior service (costs) credits arising during period	(26)	(1)	345
Defined benefit plans sponsored by equity affiliates - benefit (cost)	23	19	(19)
Income taxes on defined benefit plans	(230)	(44)	(505)
Total	631	200	443
Other Comprehensive Gain, Net of Tax	607	254	448
Comprehensive Income	15,467	9,523	17
Comprehensive income attributable to noncontrolling interests	(36)	(74)	(66)
Comprehensive Income (Loss) Attributable to Chevron Corporation	$ 15,431	$ 9,449	$ (49)

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions		Dec. 31, 2018	Dec. 31, 2017
Assets
Cash and cash equivalents		$ 9,342	$ 4,813
Time deposits		950	0
Marketable securities		53	9
Accounts and notes receivable (less allowance: 2018 - $869; 2017 - $490)		15,050	15,353
Inventories:
Crude oil and petroleum products		3,383	3,142
Chemicals		487	476
Materials, supplies and other		1,834	1,967
Total inventories		5,704	5,585
Prepaid expenses and other current assets		2,922	2,800
Total Current Assets		34,021	28,560
Long-term receivables, net		1,942	2,849
Investments and advances		35,546	32,497
Properties, plant and equipment, at cost		340,244	344,485
Less: Accumulated depreciation, depletion and amortization		171,037	166,773
Properties, plant and equipment, net		169,207	177,712
Deferred charges and other assets		6,766	7,017
Goodwill		4,518	4,531
Assets held for sale		1,863	640
Total Assets		253,863	253,806
Liabilities and Equity
Short-term debt		5,726	5,192
Accounts payable		13,953	14,565
Accrued liabilities		4,927	5,267
Federal and other taxes on income		1,628	1,600
Other taxes payable		937	1,113
Total Current Liabilities		27,171	27,737
Long-term debt	[1]	28,733	33,571
Deferred credits and other noncurrent obligations		19,742	21,106
Noncurrent deferred income taxes		15,921	14,652
Noncurrent employee benefit plans		6,654	7,421
Total Liabilities	[2]	98,221	104,487
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, 2018 and 2017)		1,832	1,832
Capital in excess of par value		17,112	16,848
Retained earnings		180,987	174,106
Accumulated other comprehensive losses		(3,544)	(3,589)
Deferred compensation and benefit plan trust		(240)	(240)
Treasury stock, at cost (2018 - 539,838,890 shares; 2017 - 537,974,695)		(41,593)	(40,833)
Total Chevron Corporation Stockholders' Equity		154,554	148,124
Noncontrolling interests		1,088	1,195
Total Equity		155,642	149,319
Total Liabilities and Equity		$ 253,863	$ 253,806
[1]	Includes capital lease obligations of $127 and $94 at December 31, 2018 and 2017, respectively.
[2]	Refer to Note 23, "Other Contingencies and Commitments" beginning on page 86.

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Allowance for accounts and notes receivable, current	$ 869	$ 490
Preferred stock, shares authorized (in shares)	100,000,000	100,000,000
Preferred stock, par value (usd per share)	$ 1	$ 1
Preferred stock, shares issued (in shares)	0	0
Common stock, shares authorized (in shares)	6,000,000,000	6,000,000,000
Common stock, par value (usd per share)	$ 0.75	$ 0.75
Common stock, shares issued (in shares)	2,442,676,580	2,442,676,580
Treasury stock, shares (in shares)	539,838,890	537,974,695
Capital lease obligations	$ 127	$ 94

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating Activities
Net Income (Loss)		$ 14,860	$ 9,269	$ (431)
Adjustments
Depreciation, depletion and amortization		19,419	19,349	19,457
Dry hole expense		687	198	489
Distributions less than income from equity affiliates	[1]	(3,580)	(2,380)	(1,549)
Net before-tax gains on asset retirements and sales		(619)	(2,195)	(1,149)
Net foreign currency effects		123	131	186
Deferred income tax provision		1,050	(3,203)	(3,835)
Net decrease (increase) in operating working capital	[2]	(718)	520	(327)
Decrease (increase) in long-term receivables		418	(368)	(131)
Net decrease (increase) in other deferred charges	[2]	0	(254)	178
Cash contributions to employee pension plans		(1,035)	(980)	(870)
Other		13	251	672
Net Cash Provided by Operating Activities	[1],[2]	30,618	20,338	12,690
Investing Activities
Capital expenditures		(13,792)	(13,404)	(18,109)
Proceeds and deposits related to asset sales and returns of investment	[1],[2]	2,392	5,096	3,476
Net maturities of (investments in) time deposits		(950)	0	0
Net sales (purchases) of marketable securities		(51)	4	297
Net repayment (borrowing) of loans by equity affiliates		111	(16)	(2,034)
Net Cash Used for Investing Activities	[1],[2]	(12,290)	(8,320)	(16,370)
Financing Activities
Net borrowings (repayments) of short-term obligations		2,021	(5,142)	2,130
Proceeds from issuances of long-term debt		218	3,991	6,924
Repayments of long-term debt and other financing obligations		(6,741)	(6,310)	(1,584)
Cash dividends - common stock		(8,502)	(8,132)	(8,032)
Distributions to noncontrolling interests		(91)	(78)	(63)
Net sales (purchases) of treasury shares		(604)	1,117	650
Net Cash Provided by (Used for) Financing Activities		(13,699)	(14,554)	25
Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash		(91)	65	(53)
Net Change in Cash, Cash Equivalents and Restricted Cash		4,538	(2,471)	(3,708)
Cash, Cash Equivalents and Restricted Cash at January 1		5,943	8,414	12,122
Cash, Cash Equivalents and Restricted Cash at December 31		$ 10,481	$ 5,943	$ 8,414
[1]	2017 and 2016 adjusted to conform to ASU 2016-15. Refer to Note 3, "Information Relating to the Consolidated Statement of Cash Flows" beginning on page 59.
[2]	2017 and 2016 adjusted to conform to ASU 2016-18. Refer to Note 3, "Information Relating to the Consolidated Statement of Cash Flows" beginning on page 59.

Consolidated Statement of Equit

Consolidated Statement of Equity - USD ($) shares in Thousands, $ in Millions		Total	Common Stock	[1]	Retained Earnings	Acc. Other Comprehensive Income (Loss)	Treasury Stock (at cost)	Chevron Corp. Stockholders' Equity	Noncontrolling Interests
Balance at January 1 at Dec. 31, 2015		$ 153,886	$ 17,922		$ 181,578	$ (4,291)	$ (42,493)	$ 152,716	$ 1,170
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Treasury stock transactions		265	265					265
Net Income (Loss)		(431)			(497)			(497)	66
Cash dividends		(8,095)			(8,032)			(8,032)	(63)
Stock dividends		(3)			(3)			(3)
Other comprehensive income		448				448		448
Purchases of treasury shares		(2)					(2)	(2)
Issuances of treasury shares		661					661	661
Other changes, net		(7)							(7)
Balance at December 31 at Dec. 31, 2016		$ 146,722	18,187		173,046	(3,843)	(41,834)	145,556	1,166
Beginning balance, shares issued (in shares) at Dec. 31, 2015	[2]	2,442,677
Beginning balance, treasury shares (in shares) at Dec. 31, 2015		(559,863)
Beginning balance, shares outstanding (in shares) at Dec. 31, 2015		1,882,814
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Purchases (in shares)		(20)
Issuances (in shares)		8,713
Ending balance, shares issued (in shares) at Dec. 31, 2016	[2]	2,442,677
Ending balance, treasury shares (in shares) at Dec. 31, 2016		(551,170)
Ending balance, shares outstanding (in shares) at Dec. 31, 2016		1,891,507
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Treasury stock transactions		$ 253	253					253
Net Income (Loss)		9,269			9,195			9,195	74
Cash dividends		(8,210)			(8,132)			(8,132)	(78)
Stock dividends		(3)			(3)			(3)
Other comprehensive income		254				254		254
Purchases of treasury shares		(1)					(1)	(1)
Issuances of treasury shares		1,002					1,002	1,002
Other changes, net		33							33
Balance at December 31 at Dec. 31, 2017		$ 149,319	18,440		174,106	(3,589)	(40,833)	148,124	1,195
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Purchases (in shares)		(10)
Issuances (in shares)		13,205
Ending balance, shares issued (in shares) at Dec. 31, 2017	[2]	2,442,677
Ending balance, treasury shares (in shares) at Dec. 31, 2017		(537,975)
Ending balance, shares outstanding (in shares) at Dec. 31, 2017		1,904,702
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Treasury stock transactions		$ 264	264					264
Net Income (Loss)		14,860			14,824			14,824	36
Cash dividends		(8,593)			(8,502)			(8,502)	(91)
Stock dividends		(3)			(3)			(3)
Other comprehensive income		607				607		607
Purchases of treasury shares		(1,751)					(1,751)	(1,751)
Issuances of treasury shares		991					991	991
Other changes, net	[3]	(52)			562	(562)			(52)
Balance at December 31 at Dec. 31, 2018		$ 155,642	$ 18,704		$ 180,987	$ (3,544)	$ (41,593)	$ 154,554	$ 1,088
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Purchases (in shares)		(14,912)
Issuances (in shares)		13,048
Ending balance, shares issued (in shares) at Dec. 31, 2018	[2]	2,442,677
Ending balance, treasury shares (in shares) at Dec. 31, 2018		(539,839)
Ending balance, shares outstanding (in shares) at Dec. 31, 2018		1,902,838
[1]	Beginning and ending balances for all periods include capital in excess of par, common stock issued at par for $1,832, and $(240) associated with Chevron's Benefit Plan Trust. Changes reflect capital in excess of par.
[2]	Beginning and ending total issued share balances include 14,168 shares associated with Chevron's Benefit Plan Trust.
[3]	In 2018, Chevron reclassified stranded tax effects in "Accumulated other comprehensive loss" to "Retained earnings" in conjunction with the adoption of ASU 2018-02. Refer to Note 2, "Changes in Accumulated Other Comprehensive Losses" on page 58 and Note 4, "New Accounting Standards" on page 60.

Consolidated Statement of Equ_2

Consolidated Statement of Equity (Parenthetical) shares in Thousands, $ in Millions	Dec. 31, 2018USD ($)shares
Statement of Stockholders' Equity [Abstract]
Common stock issued at par	$ 1,832
Benefit Plan Trust	$ (240)
Number of Chevron treasury stocks held in benefit plan trust for funding obligations | shares	14,168

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2018
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 circumstances change and additional information becomes known. 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. 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. 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 and Consolidated Statement of Equity. 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 are primarily stated at cost or net realizable value. 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 20 , beginning on page 79 , 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 8 , beginning on page 63 , 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 4 , on page 88 , 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. Impairments 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 annually at December 31, or more frequently if an event occurs or circumstances change that would more likely than not reduce the fair value of the reporting unit below its carrying amount. Environmental Expenditures Environmental expenditures that relate to ongoing operations or to conditions caused by past operations are expensed. Expenditures that create future benefits or contribute to future revenue generation are capitalized. Liabilities related to future remediation costs are recorded when environmental assessments or cleanups or both are probable and the costs can be reasonably estimated. For crude oil, natural gas and mineral-producing properties, a liability for an ARO is made in accordance with accounting standards for asset retirement and environmental obligations. Refer to Note 2 4 , on page 88 , 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 The company accounts for each delivery order of crude oil, natural gas, petroleum and chemical products as a separate performance obligation. Revenue is recognized when the performance obligation is satisfied, which typically occurs at the point in time when control of the product transfers to the customer. Payment is generally due within 30 days of delivery. The company accounts for delivery transportation as a fulfillment cost, not a separate performance obligation, and recognizes these costs as an operating expense in the period when revenue for the related commodity is recognized. Revenue is measured as the amount the company expects to receive in exchange for transferring commodities to the customer. The company’s commodity sales are typically based on prevailing market-based prices and may include discounts and allowances. Until market prices become known under terms of the company’s contracts, the transaction price included in revenue is based on the company’s estimate of the most likely outcome. Discounts and allowances are estimated using a combination of historical and recent data trends. When deliveries contain multiple products, an observable standalone selling price is generally used to measure revenue for each product. The company includes estimates in the transaction price only to the extent that a significant reversal of revenue is not probable in subsequent periods. 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 net basis in "Taxes other than on income" on the Consolidated Statement of Income, on page 50 . 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. Prior to the adoption of ASC 606 on January 1, 2018, revenues associated with sales of crude oil, natural gas, petroleum and chemicals products, and all other sources were recorded when title passed 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 were 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 were presented on a gross basis 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 in which an employee becomes eligible to retain the award at retirement. The company’s Long-Term Incentive Plan (LTIP) awards include stock options and stock appreciation rights, which have graded vesting provisions by which one-third of each award vests on each of the first, second and third anniversaries of the date of grant. In addition, performance shares granted under the company's LTIP will vest at the end of the three -year performance period. For awards granted under the company's LTIP beginning in 2017, stock options and stock appreciation rights 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 unit awards have cliff vesting by which the total award will vest on January 31 on or after the fifth anniversary of the grant date, subject to adjustment upon termination pursuant to the satisfaction of certain criteria. 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, 2018
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 ended December 31, 2018 , are reflected in the table below. Currency Translation Adjustments Unrealized Holding Gains (Losses) on Securities Derivatives Defined Benefit Plans Total Balance at December 31, 2015 $ (140 ) $ (29 ) $ (2 ) $ (4,120 ) $ (4,291 ) Components of Other Comprehensive Income (Loss) 1 : Before Reclassifications (22 ) 27 — (161 ) (156 ) Reclassifications 2 — — — 604 604 Net Other Comprehensive Income (Loss) (22 ) 27 — 443 448 Balance at December 31, 2016 $ (162 ) $ (2 ) $ (2 ) $ (3,677 ) $ (3,843 ) Components of Other Comprehensive Income (Loss) 1 : Before Reclassifications 57 (3 ) — (310 ) (256 ) Reclassifications 2 — — — 510 510 Net Other Comprehensive Income (Loss) 57 (3 ) — 200 254 Balance at December 31, 2017 $ (105 ) $ (5 ) $ (2 ) $ (3,477 ) $ (3,589 ) Components of Other Comprehensive Income (Loss) 1 : Before Reclassifications (19 ) (5 ) — 28 4 Reclassifications 2 — — — 603 603 Net Other Comprehensive Income (Loss) (19 ) (5 ) — 631 607 Stranded Tax Reclassification to Retained Earnings 3 — — — (562 ) (562 ) Balance at December 31, 2018 $ (124 ) $ (10 ) $ (2 ) $ (3,408 ) $ (3,544 ) 1 All amounts are net of tax. 2 Refer to Note 22 beginning on page 81 , for reclassified components totaling $779 that are included in employee benefit costs for the year ended December 31, 2018 . Related income taxes for the same period, totaling $176 , are reflected in Income Tax Expense on the Consolidated Statement of Income. All other reclassified amounts were insignificant. 3 Stranded tax reclassification to retained earnings per ASU 2018-02. Refer to Note 4 , " New Accounting Standards " on page 60 .

Information Relating to the Con

Information Relating to the Consolidated Statement of Cash Flows	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2016 Net decrease (increase) in operating working capital was composed of the following: Decrease (increase) in accounts and notes receivable $ 437 $ (915 ) $ (2,121 ) Decrease (increase) in inventories (424 ) (267 ) 603 Decrease (increase) in prepaid expenses and other current assets 1 (149 ) 173 829 Increase (decrease) in accounts payable and accrued liabilities 1 (494 ) 998 366 Increase (decrease) in income and other taxes payable (88 ) 531 (4 ) Net decrease (increase) in operating working capital $ (718 ) $ 520 $ (327 ) Net cash provided by operating activities includes the following cash payments: Interest on debt (net of capitalized interest) $ 736 $ 265 $ 158 Income taxes 4,748 3,132 1,935 Proceeds and deposits related to asset sales and returns of investment consisted of the following gross amounts: Proceeds and deposits related to asset sales 1 $ 2,000 $ 4,930 $ 3,154 Returns of investment from equity affiliates 2 392 166 322 Proceeds and deposits related to asset sales and returns of investment $ 2,392 $ 5,096 $ 3,476 Net maturities (investments) of time deposits consisted of the following gross amounts: Investments in time deposits $ (950 ) $ — $ — Maturities of time deposits — — — Net maturities of (investments in) time deposits $ (950 ) $ — $ — Net sales (purchases) of marketable securities consisted of the following gross amounts: Marketable securities purchased $ (51 ) $ (3 ) $ (9 ) Marketable securities sold — 7 306 Net sales (purchases) of marketable securities $ (51 ) $ 4 $ 297 Net repayment (borrowing) of loans by equity affiliates: Borrowing of loans by equity affiliates $ — $ (142 ) $ (2,341 ) Repayment of loans by equity affiliates 111 126 307 Net repayment (borrowing) of loans by equity affiliates $ 111 $ (16 ) $ (2,034 ) Net borrowings (repayments) of short-term obligations consisted of the following gross and net amounts: Proceeds from issuances of short-term obligations $ 2,486 $ 5,051 $ 14,778 Repayments of short-term obligations (4,136 ) (8,820 ) (12,558 ) Net borrowings (repayments) of short-term obligations with three months or less maturity 3,671 (1,373 ) (90 ) Net borrowings (repayments) of short-term obligations $ 2,021 $ (5,142 ) $ 2,130 1 2017 and 2016 adjusted to conform to ASU 2016-18. 2 Per ASU 2016-15. A loan to Tengizchevroil LLP for the development of the Future Growth and Wellhead Pressure Management Project represents the majority of "Net borrowing of loans by equity affiliates" in 2016. The “Net sales (purchases) of treasury shares” represents the cost of common shares acquired less the cost of shares issued for share-based compensation plans. Purchases totaled $1,751 , $1 and $2 in 2018 , 2017 and 2016 , respectively. The company purchased 14.9 million shares under its stock repurchase plan for $ 1,750 in 2018 . No shares were repurchased under the plan in 2017 or 2016 . The Consolidated Statement of Cash Flows excludes changes to the Consolidated Balance Sheet that did not affect cash. "Depreciation, depletion and amortization," "Dry hole expense" and "Deferred income tax provision" collectively include approximately $1.1 billion in non-cash reductions to properties, plant and equipment recorded in 2018 relating to impairments and other non-cash charges. Refer also to Note 2 4 , on page 88 , 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, 2018 . 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 2018 2017 2016 Additions to properties, plant and equipment * $ 13,384 $ 13,222 $ 17,742 Additions to investments 65 25 55 Current-year dry hole expenditures 344 157 313 Payments for other liabilities and assets, net (1 ) — (1 ) Capital expenditures 13,792 13,404 18,109 Expensed exploration expenditures 523 666 544 Assets acquired through capital lease obligations and other financing obligations 75 8 5 Capital and exploratory expenditures, excluding equity affiliates 14,390 14,078 18,658 Company's share of expenditures by equity affiliates 5,716 4,743 3,770 Capital and exploratory expenditures, including equity affiliates $ 20,106 $ 18,821 $ 22,428 * Excludes non-cash additions of $25 in 2018 , $1,183 in 2017 and $56 in 2016 . On January 1, 2018, Chevron adopted Accounting Standards Updates (ASU) 2016-15 and 2016-18, which require retrospective adjustment of prior periods in the Statement of Cash Flows. In addition to other requirements, ASU 2016-15 specifies new standards for the classification of distributions from equity affiliates. In adopting these new standards, Chevron utilized the cumulative earnings approach to evaluate returns on and returns of investment from equity affiliates. For the year ended 2017 and 2016 , a total of $166 and $322 , respectively, was reclassified from “Distributions less than income from equity affiliates” to “Proceeds and deposits related to asset sales and returns of investment.” Adoption of ASU 2016-18 requires the inclusion of restricted cash and associated changes in restricted cash in the Consolidated Statement of Cash Flows. The impact of ASU 2016-18 is captured across several line items in the Statement of Cash Flows, including “Net decrease (increase) in operating working capital,” “Decrease (increase) in other deferred charges,” and “Proceeds and deposits related to asset sales and returns of investment” with associated net changes captured in both “Net Cash Provided by Operating Activities” and “Net Cash Used for Investing Activities.” The line item “Net sales (purchases) of other short-term investments” was removed in conjunction with the adoption of ASU 2016-18. The table below quantifies the beginning and ending balances of restricted cash and restricted cash equivalents in the Consolidated Balance Sheet: Year ended December 31 2018 2017 2016 2015 Cash and cash equivalents $ 9,342 $ 4,813 $ 6,988 $ 11,022 Restricted cash included in "Prepaid expenses and other current assets" 341 405 488 196 Restricted cash included in "Deferred charges and other assets" 798 725 938 904 Total cash, cash equivalents and restricted cash $ 10,481 $ 5,943 $ 8,414 $ 12,122

New Accounting Standards

New Accounting Standards	12 Months Ended
	Dec. 31, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Standards	New Accounting Standards Revenue Recognition (Topic 606): Revenue from Contracts with Customers On January 1, 2018, Chevron adopted ASU 2014-09 and its related amendments using the modified retrospective transition method, which did not require the restatement of prior periods. The impact of the adoption of the standard did not have a material effect on the company’s consolidated financial statements. For additional information on the company’s revenue, refer to Note 25 beginning on page 88 . Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20) On January 1, 2018, the company adopted ASU 2017-05, which provides clarification regarding the guidance on accounting for the derecognition of nonfinancial assets. The adoption of the standard had no impact on the company’s consolidated financial statements. Compensation - Retirement Benefits (Topic 715) Effective January 1, 2018, Chevron adopted ASU 2017-07 on a retrospective basis. The standard requires the disaggregation of the service cost component from the other components of net periodic benefit cost and allows only the service cost component of net benefit cost to be eligible for capitalization. The effects of retrospective adoption on the Consolidated Statement of Income for 2017 and 2016 were to move $310 and $366 from "Operating expenses" and $338 and $379 from "Selling, general and administrative expenses" to "Other components of net periodic benefits cost," respectively. Statement of Cash Flows (Topic 230) Classification of Certain Cash Receipts and Cash Payments Effective January 1, 2018, Chevron adopted ASU 2016-15 on a retrospective basis. The standard provides clarification on how certain cash receipts and cash payments are presented and classified on the Consolidated Statement of Cash Flows. The adoption of this ASU did not have a material impact on the company's Consolidated Statement of Cash Flows. For additional information, refer to Note 3 beginning on page 59 . Statement of Cash Flows (Topic 230) Restricted Cash Effective January 1, 2018, Chevron adopted ASU 2016-18 on a retrospective basis. The standard requires an entity to explain the changes in the total of cash, cash equivalents, restricted cash and restricted cash equivalents on the Consolidated Statement of Cash Flows and to provide a reconciliation to the Consolidated Balance Sheet when the cash, cash equivalents, restricted cash and restricted cash equivalents are not separately presented or are presented in more than one line item on the Consolidated Balance Sheet. The company’s restricted cash balances are now included in the beginning and ending balances on the Consolidated Statement of Cash Flows. For additional information, refer to Note 3 beginning on page 59 . Income Statement - Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income In fourth quarter 2018, the company elected to early adopt ASU 2018-02, which permits the reclassification of stranded tax effects in accumulated other comprehensive income as a result of U.S. tax reform. Accordingly, Chevron reclassified $562 from "Accumulated other comprehensive losses" to "Retained earnings" associated with the reduction of the U.S. statutory tax rate from 35 percent to 21 percent. In accordance with its accounting policy, the company releases stranded income tax effects from accumulated other comprehensive income in the period the underlying activity ceases to exist. ASU 2018-02 allowed for the reclassification of stranded tax effects as a result of the change in tax rates due to U.S. tax reform to be recorded upon adoption of the ASU, rather than at the actual date that the underlying activity ceases to exist. For additional detail, refer to Note 2 beginning on page 58 . Leases (Topic 842) In February 2016, the Financial Accounting Standards Board (FASB) issued ASU 2016-02, which became effective for the company January 1, 2019. The standard requires that lessees present right-of-use assets and lease liabilities on the Consolidated Balance Sheet. The company plans to elect the short-term lease exception provided for in the standard and therefore will only recognize right-of-use assets and lease liabilities for leases with a term greater than one year. The company further intends to elect the option to apply the transition provisions of the new standard at the adoption date instead of the earliest comparative period presented in the financial statements. The company plans to elect the package of practical expedients to not re-evaluate existing lease contracts or lease classifications and therefore will not make changes to those leases already recognized on the Consolidated Balance Sheet under ASC 840 until the leases are fully amortized, amended, or modified. In addition, the company will not reassess initial direct costs for any existing leases. The company intends to apply the land easement practical expedient. Chevron plans to elect the practical expedient to not separate non-lease components from lease components for most asset classes except for certain asset classes that have significant non-lease (i.e., service) components in addition to the lease component. The company will reclassify some contracts, currently not classified as leases, as operating leases under the new standard. The company completed accounting policy and disclosure updates and system implementation necessary to meet the standard's requirements. The company does not expect the adoption of the ASU to have a material impact on finance leases, which are currently referred to as capital leases. The company estimates that the operating lease right-of-use assets and lease liabilities on the Consolidated Balance Sheet are approximately $4 billion , as of January 1, 2019. The company expects the implementation of the standard will have a minimal impact on the Consolidated Statement of Income and Consolidated Statement of Cash Flows. 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.

Lease Commitments

Lease Commitments	12 Months Ended
	Dec. 31, 2018
Leases [Abstract]
Lease Commitments	Lease Commitments Certain noncancelable leases are classified as capital leases, and the leased assets are included as part of “Properties, plant and equipment, at cost” on the Consolidated Balance Sheet. Such leasing arrangements involve crude oil production and processing equipment, vessels, 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 below: At December 31 2018 2017 Upstream $ 719 $ 678 Downstream 99 99 All Other — — Total 818 777 Less: Accumulated amortization 617 515 Net capitalized leased assets $ 201 $ 262 Rental expenses incurred for operating leases during 2018 , 2017 and 2016 were as follows: Year ended December 31 2018 2017 2016 Minimum rentals $ 820 $ 726 $ 943 Contingent rentals 1 1 2 Total 821 727 945 Less: Sublease rental income 5 6 7 Net rental expense $ 816 $ 721 $ 938 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, 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, 2018 , 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 2019 $ 540 $ 30 2020 492 22 2021 378 17 2022 242 16 2023 166 16 Thereafter 341 132 Total $ 2,159 $ 233 Less: Amounts representing interest and executory costs $ (88 ) Net present values 145 Less: Capital lease obligations included in short-term debt (18 ) Long-term capital lease obligations $ 127 * Excluded from the table is an executed but not-yet-commenced capital lease with payments of $14, $15, $22, $21, $21, and $219 for 2019, 2020, 2021, 2022, 2023, and thereafter, respectively.

Summarized Financial Data - Che

Summarized Financial Data - Chevron U.S.A. Inc.	12 Months Ended
	Dec. 31, 2018
Summarized Financial Data of Subsidiary One [Abstract]
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 2018 2017 2016 Sales and other operating revenues $ 125,076 $ 104,054 $ 83,715 Total costs and other deductions 121,351 103,904 87,429 Net income (loss) attributable to CUSA 4,334 4,842 (1,177 ) At December 31 2018 2017 Current assets $ 12,819 $ 12,163 Other assets 55,814 54,994 Current liabilities 16,376 17,379 Other liabilities 12,906 12,541 Total CUSA net equity $ 39,351 $ 37,237 Memo: Total debt $ 3,049 $ 3,056

Summarized Financial Data - Ten

Summarized Financial Data - Tengizchevroil LLP	12 Months Ended
	Dec. 31, 2018
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 14 , beginning on page 69 , for a discussion of TCO operations. Summarized financial information for 100 percent of TCO is presented in the table below: Year ended December 31 2018 2017 2016 Sales and other operating revenues $ 17,260 $ 13,363 $ 10,460 Costs and other deductions 7,446 6,507 6,822 Net income attributable to TCO 6,908 4,841 2,563 At December 31 2018 2017 Current assets $ 2,374 $ 4,239 Other assets 34,727 26,411 Current liabilities 3,069 2,517 Other liabilities 6,357 6,266 Total TCO net equity $ 27,675 $ 21,867

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The tables 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, 2018 , and December 31, 2017 . 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, 2018 . 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 did not have any individually material impairments in 2018 or 2017. Investments and Advances The company did not have any individually material impairments of investments and advances in 2018 or 2017 . Assets and Liabilities Measured at Fair Value on a Recurring Basis At December 31, 2018 At December 31, 2017 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Marketable securities $ 53 $ 53 $ — $ — $ 9 $ 9 $ — $ — Derivatives 283 185 98 — 22 — 22 — Total assets at fair value $ 336 $ 238 $ 98 $ — $ 31 $ 9 $ 22 $ — Derivatives 12 — 12 — 124 78 46 — Total liabilities at fair value $ 12 $ — $ 12 $ — $ 124 $ 78 $ 46 $ — 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 2018 Total Level 1 Level 2 Level 3 Year 2017 Properties, plant and equipment, net (held and used) $ 102 $ — $ 62 $ 40 $ 97 $ 603 $ — $ — $ 603 $ 658 Properties, plant and equipment, net (held for sale) 1,694 — 1,273 421 638 1,378 — 1,378 — 363 Investments and advances 81 — 20 61 69 28 — 1 27 26 Total nonrecurring assets at fair value $ 1,877 $ — $ 1,355 $ 522 $ 804 $ 2,009 $ — $ 1,379 $ 630 $ 1,047 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 $9,342 and $4,813 at December 31, 2018 , and December 31, 2017 , respectively. The instruments held in "Time deposits" are bank time deposits with maturities greater than 90 days and had carrying/fair values of $950 and zero at December 31, 2018, and December 31, 2017, respectively. The fair values of cash, cash equivalents and bank time deposits are classified as Level 1 and reflect the cash that would have been received if the instruments were settled at December 31, 2018 . "Cash and cash equivalents” do not include investments with a carrying/fair value of $1,139 and $1,130 at December 31, 2018 , and December 31, 2017 , respectively. At December 31, 2018 , these investments are classified as Level 1 and include restricted funds related to certain upstream abandonment activities, tax payments and a financing program, which are reported in “Deferred charges and other assets” on the Consolidated Balance Sheet. Long-term debt, excluding capital lease obligations, of $18,706 and $23,477 at December 31, 2018 , and December 31, 2017 , respectively, had estimated fair values of $18,729 and $23,943 , respectively. Long-term debt primarily includes corporate issued bonds. The fair value of corporate bonds is $17,858 and classified as Level 1. The fair value of other long-term debt is $871 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, 2018 and 2017 , were not material.

Financial and Derivative Instru

Financial and Derivative Instruments	12 Months Ended
	Dec. 31, 2018
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, 2018 , December 31, 2017 , and December 31, 2016 , 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 2018 2017 Commodity Accounts and notes receivable, net $ 279 $ 22 Commodity Long-term receivables, net 4 — Total assets at fair value $ 283 $ 22 Commodity Accounts payable $ 12 $ 122 Commodity Deferred credits and other noncurrent obligations — 2 Total liabilities at fair value $ 12 $ 124 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 2018 2017 2016 Commodity Sales and other operating revenues $ 135 $ (105 ) $ (269 ) Commodity Purchased crude oil and products (33 ) (9 ) (31 ) Commodity Other income 3 (2 ) — $ 105 $ (116 ) $ (300 ) The table below represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at December 31, 2018 and December 31, 2017 . Consolidated Balance Sheet: The Effect of Netting Derivative Assets and Liabilities Gross Amounts Recognized Gross Amounts Offset Net Amounts Presented Gross Amounts Not Offset Net Amounts At December 31, 2018 Derivative Assets $ 3,685 $ 3,402 $ 283 $ — $ 283 Derivative Liabilities $ 3,414 $ 3,402 $ 12 $ — $ 12 At December 31, 2017 Derivative Assets $ 1,169 $ 1,147 $ 22 $ — $ 22 Derivative Liabilities $ 1,271 $ 1,147 $ 124 $ — $ 124 Derivative assets and liabilities are classified on the Consolidated Balance Sheet as accounts and notes receivable, long-term receivables, accounts payable, and deferred credits and other noncurrent obligations. Amounts not offset on the Consolidated Balance Sheet represent positions that do not meet all the conditions for "a right of offset." Concentrations of Credit Risk The company’s financial instruments that are exposed to concentrations of credit risk consist primarily of its cash equivalents, time deposits, marketable securities, derivative financial instruments and trade receivables. The company’s short-term investments are placed with a wide array of financial institutions with high credit ratings. Company investment policies limit the company’s exposure both to credit risk and to concentrations of credit risk. Similar policies on diversification and creditworthiness are applied to the company’s counterparties in derivative instruments. The trade receivable balances, reflecting the company’s diversified sources of revenue, are dispersed among the company’s broad customer base worldwide. As a result, the company believes concentrations of credit risk are limited. The company routinely assesses the financial strength of its customers. When the financial strength of a customer is not considered sufficient, alternative risk mitigation measures may be deployed, including requiring pre-payments, letters of credit or other acceptable collateral instruments to support sales to customers.

Assets Held For Sale

Assets Held For Sale	12 Months Ended
	Dec. 31, 2018
Assets Held For Sale [Abstract]
Assets Held For Sale	Assets Held for Sale At December 31, 2018 , the company classified $1,863 of net properties, plant and equipment as “Assets held for sale” on the Consolidated Balance Sheet. These assets are primarily associated with upstream operations that are anticipated to be sold in the next 12 months. The revenues and earnings contributions of these assets in 2018 were not material.

Equity

Equity	12 Months Ended
	Dec. 31, 2018
Equity [Abstract]
Equity	Equity Retained earnings at December 31, 2018 and 2017 , included approximately $22,362 and $18,473 , respectively, for the company’s share of undistributed earnings of equity affiliates. At December 31, 2018 , about 78 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, 748,211 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, 2018
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 21 , “Stock Options and Other Share-Based Compensation,” beginning on page 80 ). The table below sets forth the computation of basic and diluted EPS: Year ended December 31 2018 2017 2016 Basic EPS Calculation Earnings available to common stockholders - Basic 1 $ 14,824 $ 9,195 $ (497 ) Weighted-average number of common shares outstanding 2 1,897 1,882 1,872 Add: Deferred awards held as stock units 1 1 1 Total weighted-average number of common shares outstanding 1,898 1,883 1,873 Earnings per share of common stock - Basic $ 7.81 $ 4.88 $ (0.27 ) Diluted EPS Calculation Earnings available to common stockholders - Diluted 1 $ 14,824 $ 9,195 $ (497 ) Weighted-average number of common shares outstanding 2 1,897 1,882 1,872 Add: Deferred awards held as stock units 1 1 1 Add: Dilutive effect of employee stock-based awards 16 15 — Total weighted-average number of common shares outstanding 1,914 1,898 1,873 Earnings per share of common stock - Diluted $ 7.74 $ 4.85 $ (0.27 ) 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, 2018
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 are not allocated to the operating segments. However, operating segments are billed for the direct use of corporate services. Nonbillable costs remain at the corporate level in “All Other.” Earnings by major operating area are presented in the following table: Year ended December 31 2018 2017 2016 Upstream United States $ 3,278 $ 3,640 $ (2,054 ) International 10,038 4,510 (483 ) Total Upstream 13,316 8,150 (2,537 ) Downstream United States 2,103 2,938 1,307 International 1,695 2,276 2,128 Total Downstream 3,798 5,214 3,435 Total Segment Earnings 17,114 13,364 898 All Other Interest expense (713 ) (264 ) (168 ) Interest income 137 60 58 Other (1,714 ) (3,965 ) (1,285 ) Net Income (Loss) Attributable to Chevron Corporation $ 14,824 $ 9,195 $ (497 ) Segment Assets Segment assets do not include intercompany investments or receivables. Assets at year-end 2018 and 2017 are as follows: At December 31 2018 2017 Upstream United States $ 42,594 $ 40,770 International 153,861 159,612 Goodwill 4,518 4,531 Total Upstream 200,973 204,913 Downstream United States 23,866 23,202 International 15,622 17,434 Total Downstream 39,488 40,636 Total Segment Assets 240,461 245,549 All Other United States 5,100 4,938 International 8,302 3,319 Total All Other 13,402 8,257 Total Assets – United States 71,560 68,910 Total Assets – International 177,785 180,365 Goodwill 4,518 4,531 Total Assets $ 253,863 $ 253,806 Segment Sales and Other Operating Revenues Operating segment sales and other operating revenues, including internal transfers, for the years 2018 , 2017 and 2016 , 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 1 2018 2017 2016 Upstream United States $ 8,926 $ 3,901 $ 3,148 Intersegment 13,965 9,341 7,217 Total United States 22,891 13,242 10,365 International 24,143 17,209 13,262 Intersegment 13,679 11,471 9,518 Total International 37,822 28,680 22,780 Total Upstream 60,713 41,922 33,145 Downstream United States 56,634 48,728 40,366 Excise and similar taxes 2 — 4,398 4,335 Intersegment 2,742 14 16 Total United States 59,376 53,140 44,717 International 68,963 57,438 46,388 Excise and similar taxes 2 — 2,791 2,570 Intersegment 1,132 1,166 1,068 Total International 70,095 61,395 50,026 Total Downstream 129,471 114,535 94,743 All Other United States 236 208 145 Intersegment 786 814 960 Total United States 1,022 1,022 1,105 International — 1 1 Intersegment 22 25 36 Total International 22 26 37 Total All Other 1,044 1,048 1,142 Segment Sales and Other Operating Revenues United States 83,289 67,404 56,187 International 107,939 90,101 72,843 Total Segment Sales and Other Operating Revenues 191,228 157,505 129,030 Elimination of intersegment sales (32,326 ) (22,831 ) (18,815 ) Total Sales and Other Operating Revenues $ 158,902 $ 134,674 $ 110,215 1 Other than the United States, no other country accounted for 10 percent or more of the company’s Sales and Other Operating Revenues. 2 Netted in "Taxes other than on income" beginning in 2018 in accordance with ASU 2014-09. Refer to Note 25 beginning on page 88. Segment Income Taxes Segment income tax expense for the years 2018 , 2017 and 2016 is as follows: Year ended December 31 2018 2017 2016 Upstream United States $ 811 $ (3,538 ) $ (1,172 ) International 4,687 2,249 166 Total Upstream 5,498 (1,289 ) (1,006 ) Downstream United States 534 (419 ) 503 International 328 650 484 Total Downstream 862 231 987 All Other (645 ) 1,010 (1,710 ) Total Income Tax Expense (Benefit) $ 5,715 $ (48 ) $ (1,729 ) Other Segment Information Additional information for the segmentation of major equity affiliates is contained in Note 14 , on page 69 . Information related to properties, plant and equipment by segment is contained in Note 17 , on page 77 .

Investments and Advances

Investments and Advances	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2018 2017 2016 Upstream Tengizchevroil $ 16,017 $ 13,121 $ 3,614 $ 2,581 $ 1,380 Petropiar 1,361 1,152 317 175 326 Petroboscan 1,315 1,080 357 154 (133 ) Caspian Pipeline Consortium 1,022 1,151 170 155 145 Angola LNG Limited 2,496 2,625 172 27 (282 ) Other 1,541 1,714 19 104 (193 ) Total Upstream 23,752 20,843 4,649 3,196 1,243 Downstream Chevron Phillips Chemical Company LLC 6,218 6,200 1,034 723 840 GS Caltex Corporation 3,924 3,826 373 290 373 Other 1,383 1,251 273 230 209 Total Downstream 11,525 11,277 1,680 1,243 1,422 All Other Other (16 ) (15 ) (2 ) (1 ) (4 ) Total equity method 35,261 $ 32,105 $ 6,327 $ 4,438 $ 2,661 Other non-equity method investments 285 392 Total investments and advances $ 35,546 $ 32,497 Total United States $ 7,500 $ 7,582 $ 1,033 $ 788 $ 802 Total International $ 28,046 $ 24,915 $ 5,294 $ 3,650 $ 1,859 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, 2018 , the company’s carrying value of its investment in TCO was about $120 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. Included in the investment is a loan to TCO to fund the development of the Future Growth and Wellhead Pressure Management Project with a balance of $2,060 , including accrued interest. See Note 7 , on page 63 , 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 heavy oil Huyapari Field and upgrading project in Venezuela’s Orinoco Belt. At December 31, 2018 , the company’s carrying value of its investment in Petropiar was approximately $136 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. Petroboscan Chevron has a 39.2 percent interest in Petroboscan, a joint stock company which operates the Boscan Field in Venezuela. At December 31, 2018 , the company’s carrying value of its investment in Petroboscan was approximately $97 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 2018 . 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 $1,022 , which includes long-term loans of $468 at year-end 2018 . 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. 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. Chevron Phillips Chemical Company LLC Chevron owns 50 percent of Chevron Phillips Chemical Company LLC. The other half is owned by Phillips 66. 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. Other Information “Sales and other operating revenues” on the Consolidated Statement of Income includes $10,378 , $8,165 and $5,786 with affiliated companies for 2018 , 2017 and 2016 , respectively. “Purchased crude oil and products” includes $6,598 , $4,800 and $3,468 with affiliated companies for 2018 , 2017 and 2016 , respectively. “Accounts and notes receivable” on the Consolidated Balance Sheet includes $884 and $1,141 due from affiliated companies at December 31, 2018 and 2017 , respectively. “Accounts payable” includes $631 and $498 due to affiliated companies at December 31, 2018 and 2017 , 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 $3,402 , $3,853 and $3,535 at December 31, 2018 , 2017 and 2016 , respectively. Affiliates Chevron Share Year ended December 31 2018 2017 2016 2018 2017 2016 Total revenues $ 84,469 $ 70,744 $ 59,253 $ 40,679 $ 33,460 $ 27,787 Income before income tax expense 16,693 13,487 6,587 6,755 5,712 3,670 Net income attributable to affiliates 13,321 10,751 5,127 6,384 4,468 2,876 At December 31 Current assets $ 32,657 $ 33,883 $ 33,406 $ 12,813 $ 13,568 $ 13,743 Noncurrent assets 87,614 82,261 75,258 36,369 32,643 28,854 Current liabilities 26,006 26,873 24,793 9,843 10,201 8,996 Noncurrent liabilities 20,000 21,447 22,671 4,446 4,224 4,255 Total affiliates' net equity $ 74,265 $ 67,824 $ 61,200 $ 34,893 $ 31,786 $ 29,346

Litigation

Litigation	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Litigation	Litigation MTBE Chevron and many other companies in the petroleum industry have used methyl tertiary butyl ether (MTBE) as a gasoline additive. Chevron is a party to seven pending lawsuits and claims, the majority of which involve numerous other petroleum marketers and refiners. Resolution of these lawsuits and claims may ultimately require the company to correct or ameliorate the alleged effects on the environment of prior release of MTBE by the company or other parties. Additional lawsuits and claims related to the use of MTBE, including personal-injury claims, may be filed in the future. The company’s ultimate exposure related to pending lawsuits and claims is not determinable. The company no longer uses MTBE in the manufacture of gasoline in the United States. Ecuador Background Chevron is a defendant in a civil lawsuit initiated in the Superior Court of Nueva Loja in Lago Agrio, Ecuador ("the provincial court"), 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 On February 14, 2011, the provincial court rendered a judgment against Chevron. 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 provincial 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 (the National Court). 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 to hear the appeal. On March 29, 2012, the matter was transferred from the provincial court to the National Court, and on November 22, 2012, the National Court agreed to hear Chevron's cassation appeal. On August 3, 2012, the provincial court 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 10, 2018, Ecuador's Constitutional Court released a decision rejecting Chevron's appeal, which sought to nullify the National Court's judgment against Chevron. No further appeals are available in Ecuador. 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 Appeal 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. 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 May 24, 2018, the Court of Appeal for Ontario upheld the Superior Court’s dismissal of Chevron Canada Limited from the case. On June 22, 2018, the Lago Agrio plaintiffs filed leave to appeal the decision of the Court of Appeal for Ontario to the Supreme Court of Canada. 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. 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 November 29, 2017, the Superior Court of Justice issued a decision dismissing the Lago Agrio plaintiffs’ recognition and enforcement proceeding based on jurisdictional grounds. On June 15, 2018, this decision became a final judgment in Brazil. On October 15, 2012, the provincial court 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. 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. On February 24, 2017, the public prosecutor in Argentina issued a supplemental opinion reaffirming its previous recommendations. On November 1, 2017, the National Court, First Instance, of Argentina issued a decision dismissing the Lago Agrio plaintiffs' recognition and enforcement proceeding based on jurisdictional grounds. On November 2, 2017, the Lago Agrio plaintiffs appealed this decision to the Federal Civil Court of Appeals. On July 3, 2018, the Federal Civil Court of Appeals affirmed the National Court, First Instance’s, dismissal of the Lago Agrio plaintiffs’ recognition and enforcement action based on jurisdictional grounds. On October 5, 2018, the Federal Civil Court of Appeals granted, in part, the admissibility of the Lago Agrio plaintiffs’ appeal to the Supreme Court of Argentina. Chevron continues to believe the Ecuadorian 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 any enforcement action. Chevron expects to continue a vigorous defense of any imposition of liability 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 January 25, 2012, the Tribunal issued its First Interim Measures Award 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 outside of Ecuador of any judgment against Chevron in the Lago Agrio case pending further order of the Tribunal. 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 outside of Ecuador of the judgment 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. On July 18, 2017, the Appeals Court of The Hague denied the Republic's appeal. On October 18, 2017, the Republic appealed the decision of the Appeals Court of The Hague to the Supreme Court of the Netherlands. 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. On August 30, 2018, the Tribunal issued its Phase Two award in favor of Chevron and Texpet. The Tribunal unanimously held that the Ecuadorian judgment was procured through fraud, bribery and corruption and was based on claims that the Republic of Ecuador had settled and released in the mid-1990s, concluding that the Ecuadorian judgment “violates international public policy” and “should not be recognized or enforced by the courts of other States.” Specifically, the Tribunal found that (i) the Republic of Ecuador breached its obligations under the 1995 and 1998 settlement agreements releasing Texpet and its affiliates from public environmental claims (the same claims on which the Ecuadorian judgment was exclusively based) and (ii) the Republic of Ecuador committed a denial of justice under customary international law and under the fair and equitable treatment provision of the BIT due to the fraud and corruption in the Lago Agrio litigation. The Tribunal also found that Texpet satisfied its environmental remediation obligations with a $40 remediation program and that Ecuador certified that Texpet had performed all of its obligations under its settlement agreement. Among other things, the Tribunal ordered the Republic of Ecuador to: (a) take immediate steps to remove the status of enforceability from the Ecuadorian judgment; (b) promptly advise in writing any State where the Lago Agrio plaintiffs may be seeking the enforcement or recognition of the Ecuadorian judgment of the Tribunal’s declarations, orders and awards; (c) take measures to “wipe out all the consequences” of Ecuador's "internationally wrongful acts in regard to the Ecuadorian judgment;" and (d) compensate Chevron for any injuries resulting from the Ecuadorian judgment. On December 10, 2018, the Republic of Ecuador filed in the District Court of The Hague a request to set aside the Tribunal's Phase Two Award. The Tribunal has not set a date for Phase Three, the third and final phase of the arbitration, at which damages for Chevron's injuries will be determined. Company's RICO Action 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 sought relief that included 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. 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, 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. On October 27, 2016, the Second Circuit denied the defendants' petitions for en banc rehearing of the opinion on their appeal. On March 27, 2017, two of the defendants filed a petition for a Writ of Certiorari to the United States Supreme Court. On June 19, 2017, the United States Supreme Court denied the defendants' petition for a Writ of Certiorari. 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, management does not believe the judgment has 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, 2018
Income Tax Disclosure [Abstract]
Taxes	Taxes Income Taxes Year ended December 31 2018 2017 2016 Income tax expense (benefit) U.S. federal Current $ (181 ) $ (382 ) $ (623 ) Deferred 738 (2,561 ) (1,558 ) State and local Current 183 (97 ) (15 ) Deferred (16 ) 66 (121 ) Total United States 724 (2,974 ) (2,317 ) International Current 4,662 3,634 2,744 Deferred 329 (708 ) (2,156 ) Total International 4,991 2,926 588 Total income tax expense (benefit) $ 5,715 $ (48 ) $ (1,729 ) 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: 2018 2017 2016 Income (loss) before income taxes United States $ 4,730 $ (441 ) $ (4,317 ) International 15,845 9,662 2,157 Total income (loss) before income taxes 20,575 9,221 (2,160 ) Theoretical tax (at U.S. statutory rate of 21% - 2018, 35% - 2017 & 2016) 4,321 3,227 (756 ) Effect of U.S. tax reform (26 ) (2,020 ) — Equity affiliate accounting effect (1,526 ) (1,373 ) (704 ) Effect of income taxes from international operations * 3,132 (130 ) 608 State and local taxes on income, net of U.S. federal income tax benefit 162 39 (44 ) Prior year tax adjustments, claims and settlements (51 ) (39 ) (349 ) Tax credits (163 ) (199 ) (188 ) Other U.S. * (134 ) 447 (296 ) Total income tax expense (benefit) $ 5,715 $ (48 ) $ (1,729 ) Effective income tax rate 27.8 % (0.5 )% 80.0 % * Includes one-time tax costs (benefits) associated with changes in uncertain tax positions and valuation allowances. The 2018 increase in income tax charge of $5,763 , from a benefit of $48 in 2017 to a charge of $5,715 in 2018, is a result of the year-over-year increase in total income before income tax expense, which is primarily due to higher crude oil realizations offset by lower gains on asset sales in 2018 compared to 2017. U.S. tax reform resulted in a benefit of $2,020 being recognized in 2017 reflecting the remeasurement of U.S. deferred tax assets and liabilities. The company’s effective tax rate changed from (0.5) percent in 2017 to 28 percent in 2018 . The change in effective tax rate is 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 and the impact of U.S. tax reform to both the 2018 and 2017 results. As noted above, U.S. tax reform resulted in the remeasurement of U.S. deferred tax assets and liabilities in 2017. The U.S. tax return for 2017 was prepared and filed in 2018 and did not result in any material change to the the provisional amounts that were recognized in 2017, and the amounts are now considered final. The company records its deferred taxes on a tax-jurisdiction basis. The reported deferred tax balances are composed of the following: At December 31 2018 2017 Deferred tax liabilities Properties, plant and equipment $ 20,159 $ 19,869 Investments and other 4,943 4,796 Total deferred tax liabilities 25,102 24,665 Deferred tax assets Foreign tax credits (10,536 ) (11,872 ) Asset retirement obligations/environmental reserves (5,328 ) (5,511 ) Employee benefits (2,787 ) (3,129 ) Deferred credits (1,373 ) (1,769 ) Tax loss carryforwards (4,948 ) (5,463 ) Other accrued liabilities (595 ) (842 ) Inventory (505 ) (336 ) Miscellaneous (3,481 ) (2,415 ) Total deferred tax assets (29,553 ) (31,337 ) Deferred tax assets valuation allowance 15,973 16,574 Total deferred taxes, net $ 11,522 $ 9,902 Deferred tax liabilities at the end of 2018 increased by approximately $400 from year-end 2017 . The increase was primarily related to property, plant and equipment temporary differences. Deferred tax assets decreased by approximately $1,800 in 2018. The decrease primarily related to lower foreign tax credits and the utilization of 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 2018 , the company had tax loss carryforwards of approximately $13,731 and tax credit carryforwards of approximately $1,198 , 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 2019 through 2036 . U.S. foreign tax credit carryforwards of $10,536 will expire between 2019 and 2028 . At December 31, 2018 and 2017 , deferred taxes were classified on the Consolidated Balance Sheet as follows: At December 31 2018 2017 Deferred charges and other assets $ (4,399 ) $ (4,750 ) Noncurrent deferred income taxes 15,921 14,652 Total deferred income taxes, net $ 11,522 $ 9,902 Enactment of U.S. tax reform in 2017 imposed a one-time U.S. federal tax on the deemed repatriation of unremitted earnings indefinitely reinvested abroad, which did not have a material impact on the company’s financial results. The indefinite reinvestment assertion continues to apply for the purpose of determining deferred tax liabilities for U.S. state and foreign withholding tax purposes. U.S. state and foreign withholding 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 $59,900 at December 31, 2018 . This amount represents earnings reinvested as part of the company’s ongoing international business. It is not practicable to estimate the amount of state and foreign taxes that might be payable on the possible remittance of earnings that are intended to be reinvested indefinitely. 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, 2018 , 2017 and 2016 . 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. 2018 2017 2016 Balance at January 1 $ 4,828 $ 3,031 $ 3,042 Foreign currency effects (6 ) 43 1 Additions based on tax positions taken in current year 239 1,853 245 Additions for tax positions taken in prior years 153 1,166 181 Reductions for tax positions taken in prior years (131 ) (90 ) (390 ) Settlements with taxing authorities in current year (13 ) (1,173 ) (36 ) Reductions as a result of a lapse of the applicable statute of limitations — (2 ) (12 ) Balance at December 31 $ 5,070 $ 4,828 $ 3,031 Approximately 82 percent of the $5,070 of unrecognized tax benefits at December 31, 2018 , 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, 2018 . For these jurisdictions, the latest years for which income tax examinations had been finalized were as follows: United States – 2013 , Nigeria – 2000 , Australia – 2006 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, 2018 , accruals of $33 for anticipated interest and penalty obligations were included on the Consolidated Balance Sheet, compared with accruals of $178 as of year-end 2017 . Income tax expense (benefit) associated with interest and penalties was $8 , $(161) and $38 in 2018 , 2017 and 2016 , respectively. Taxes Other Than on Income Year ended December 31 2018 2017 2016 United States Excise and similar taxes on products and merchandise* $ 4,830 $ 4,398 $ 4,335 Consumer excise taxes collected on behalf of third parties* (4,830 ) — — Import duties and other levies 15 11 9 Property and other miscellaneous taxes 1,577 1,824 1,680 Payroll taxes 246 241 252 Taxes on production 325 206 159 Total United States 2,163 6,680 6,435 International Excise and similar taxes on products and merchandise* 3,031 2,791 2,570 Consumer excise taxes collected on behalf of third parties* (3,031 ) — — Import duties and other levies 37 45 33 Property and other miscellaneous taxes 2,370 2,563 2,379 Payroll taxes 132 137 145 Taxes on production 165 115 106 Total International 2,704 5,651 5,233 Total taxes other than on income $ 4,867 $ 12,331 $ 11,668 * Beginning in 2018, these taxes are netted in "Taxes other than on income" in accordance with ASU 2014-09. Refer to Note 25, "Revenue" beginning on page 88.

Properties, Plant and Equipment

Properties, Plant and Equipment	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2016 2018 2017 2016 2018 2017 2016 2018 2017 2016 Upstream United States $ 88,155 $ 84,602 $ 83,929 $ 39,526 $ 38,722 $ 39,710 $ 6,434 $ 4,995 $ 4,432 $ 5,328 $ 5,527 $ 6,576 International 215,329 224,211 214,557 113,603 123,191 125,502 4,865 7,934 12,084 12,726 12,096 11,247 Total Upstream 303,484 308,813 298,486 153,129 161,913 165,212 11,299 12,929 16,516 18,054 17,623 17,823 Downstream United States 24,685 23,598 22,795 10,838 10,346 10,196 1,259 907 528 751 753 956 International 7,237 7,094 9,350 3,023 3,074 4,094 278 306 375 282 282 332 Total Downstream 31,922 30,692 32,145 13,861 13,420 14,290 1,537 1,213 903 1,033 1,035 1,288 All Other United States 4,667 4,798 5,263 2,186 2,341 2,635 224 218 198 320 677 328 International 171 182 183 31 38 49 6 4 6 12 14 18 Total All Other 4,838 4,980 5,446 2,217 2,379 2,684 230 222 204 332 691 346 Total United States 117,507 112,998 111,987 52,550 51,409 52,541 7,917 6,120 5,158 6,399 6,957 7,860 Total International 222,737 231,487 224,090 116,657 126,303 129,645 5,149 8,244 12,465 13,020 12,392 11,597 Total $ 340,244 $ 344,485 $ 336,077 $ 169,207 $ 177,712 $ 182,186 $ 13,066 $ 14,364 $ 17,623 $ 19,419 $ 19,349 $ 19,457 1 Other than the United States and Australia, no other country accounted for 10 percent or more of the company’s net properties, plant and equipment (PP&E) in 2018 . Australia had PP&E of $53,768 , $55,514 and $53,962 in 2018 , 2017 and 2016 , respectively. 2 Net of dry hole expense related to prior years’ expenditures of $343 , $42 and $175 in 2018 , 2017 and 2016 , respectively. 3 Depreciation expense includes accretion expense of $654 , $668 and $749 in 2018 , 2017 and 2016 , respectively, and impairments of $735 , $1,021 and $3,186 in 2018 , 2017 and 2016 , respectively.

Short-Term Debt

Short-Term Debt	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Short-Term Debt	Short-Term Debt At December 31 2018 2017 Commercial paper 1 $ 7,503 $ 5,379 Notes payable to banks and others with originating terms of one year or less 28 — Current maturities of long-term debt 2 4,999 6,720 Current maturities of long-term capital leases 18 15 Redeemable long-term obligations Long-term debt 3,078 3,078 Capital leases — — Subtotal 15,626 15,192 Reclassified to long-term debt (9,900 ) (10,000 ) Total short-term debt $ 5,726 $ 5,192 1 Weighted-average interest rates at December 31, 2018 and 2017, were 2.43 percent and 1.30 percent, respectively. 2 Net of unamortized discounts and issuance costs: $1 in 2018 and $2 in 2017. 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, 2018 , the company had no interest rate swaps on short-term debt. At December 31, 2018 , the company had $9,900 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 $9,575 and allows the company to convert any amounts outstanding into a term loan for a period of up to one year, and a $325 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, 2018 . The company classified $9,900 and $10,000 of short-term debt as long-term at December 31, 2018 and 2017 , 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, 2018
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Total long-term debt including capital lease obligations at December 31, 2018 , was $28,733 . The company’s long-term debt outstanding at year-end 2018 and 2017 was as follows: At December 31 2018 2017 Principal Principal 3.191% notes due 2023 $ 2,250 $ 2,250 2.954% notes due 2026 2,250 2,250 2.355% notes due 2022 2,000 2,000 1.961% notes due 2020 1,750 1,750 4.950% notes due 2019 1,500 1,500 1.561% notes due 2019 1,350 1,350 2.100% notes due 2021 1,350 1,350 2.419% notes due 2020 1,250 1,250 2.427% notes due 2020 1,000 1,000 2.895% notes due 2024 1,000 1,000 Floating rate notes due 2019 (2.905%) 1 850 850 2.193% notes due 2019 750 750 2.566% notes due 2023 750 750 3.326% notes due 2025 750 750 2.498% notes due 2022 700 700 2.411% notes due 2022 700 700 Floating rate notes due 2021 (3.313%) 1 650 650 Floating rate notes due 2022 (3.245%) 1 650 650 1.991% notes due 2020 600 600 1.686% notes due 2019 550 550 Floating rate notes due 2020 (2.948%) 2 400 400 3.400% loan 3 218 — 8.625% debentures due 2032 147 147 8.625% debentures due 2031 108 108 8.000% debentures due 2032 75 75 9.750% debentures due 2020 54 54 8.875% debentures due 2021 40 40 Medium-term notes, maturing from 2021 to 2038 (6.629%) 1 38 38 1.718% notes due 2018 — 2,000 1.365% notes due 2018 — 1,750 Floating rate notes due 2018 — 1,650 1.790% notes due 2018 — 1,250 Amortizing bank loan due 2018 — 72 Total including debt due within one year 23,730 30,234 Debt due within one year (5,000 ) (6,722 ) Reclassified from short-term debt 9,900 10,000 Unamortized discounts and debt issuance costs (24 ) (35 ) Capital lease obligations 4 127 94 Total long-term debt $ 28,733 $ 33,571 1 Weighted-average interest rate at December 31, 2018 . 2 Interest rate at December 31, 2018. 3 Maturity date is conditional upon the occurrence of certain events. 2021 is the earliest period in which the loan may become payable. 4 For details on capital lease obligations, see Note 5 beginning on page 62. Chevron has an automatic shelf registration statement that expires in May 2021. This registration statement is for an unspecified amount of nonconvertible debt securities issued or guaranteed by the company. Long-term debt excluding capital lease obligations with a principal balance of $23,730 matures as follows: 2019 – $5,000 ; 2020 – $5,054 ; 2021 – $2,272 ; 2022 – $4,050 ; 2023 – $3,003 ; and after 2023 – $4,351 . See Note 8 , beginning on page 63 , 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, 2018
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, 2018 : 2018 2017 2016 Beginning balance at January 1 $ 3,702 $ 3,540 $ 3,312 Additions to capitalized exploratory well costs pending the determination of proved reserves 207 323 465 Reclassifications to wells, facilities and equipment based on the determination of proved reserves (13 ) (113 ) (119 ) Capitalized exploratory well costs charged to expense (333 ) (39 ) (118 ) Other reductions * — (9 ) — Ending balance at December 31 $ 3,563 $ 3,702 $ 3,540 * 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 2018 2017 2016 Exploratory well costs capitalized for a period of one year or less $ 202 $ 307 $ 445 Exploratory well costs capitalized for a period greater than one year 3,361 3,395 3,095 Balance at December 31 $ 3,563 $ 3,702 $ 3,540 Number of projects with exploratory well costs that have been capitalized for a period greater than one year * 30 32 35 * Certain projects have multiple wells or fields or both. Of the $3,361 of exploratory well costs capitalized for more than one year at December 31, 2018 , $1,585 ( 14 projects) is related to projects that had drilling activities underway or firmly planned for the near future. The $1,776 balance is related to 16 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 $1,776 referenced above had the following activities associated with assessing the reserves and the projects’ economic viability: (a) $672 ( three projects) – undergoing front-end engineering and design with final investment decision expected within four years ; (b) $93 ( one project) – development concept under review by government; (c) $963 ( eight projects) – development alternatives under review; (d) $48 ( four projects) – miscellaneous activities for projects with smaller amounts suspended. While progress was being made on all 30 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 $3,361 of suspended well costs capitalized for a period greater than one year as of December 31, 2018 , represents 153 exploratory wells in 30 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 1998-2007 $ 410 31 2008-2012 1,076 61 2013-2017 1,875 61 Total $ 3,361 153 Aging based on drilling completion date of last suspended well in project: Amount Number of projects 2003-2010 $ 338 5 2011-2014 894 10 2015-2018 2,129 15 Total $ 3,361 30

Stock Options and Other Share-B

Stock Options and Other Share-Based Compensation	12 Months Ended
	Dec. 31, 2018
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 2018 , 2017 and 2016 was $105 ( $83 after tax), $137 ( $89 after tax) and $271 ( $176 after tax), respectively. In addition, compensation expense for stock appreciation rights, restricted stock, performance shares and restricted stock units was $60 ( $47 after tax), $231 ( $150 after tax) and $371 ( $241 after tax) for 2018 , 2017 and 2016 , respectively. No significant stock-based compensation cost was capitalized at December 31, 2018 , or December 31, 2017 . Cash received in payment for option exercises under all share-based payment arrangements for 2018 , 2017 and 2016 was $1,159 , $1,100 and $647 , respectively. Actual tax benefits realized for the tax deductions from option exercises were $43 , $48 and $21 for 2018 , 2017 and 2016 , respectively. Cash paid to settle performance shares, restricted stock units and stock appreciation rights was $157 , $187 and $82 for 2018 , 2017 and 2016 , 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 issued before January 1, 2017, 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 issued after January 1, 2017, contractual terms vary between three years for the performance shares and special restricted stock units, five 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 2018 , 2017 and 2016 were measured on the date of grant using the Black-Scholes option-pricing model, with the following weighted-average assumptions: Year ended December 31 2018 2017 2016 Expected term in years 1 6.5 6.3 6.3 Volatility 2 21.2 % 21.7 % 21.7 % Risk-free interest rate based on zero coupon U.S. treasury note 2.6 % 2.2 % 1.6 % Dividend yield 3.8 % 4.2 % 4.5 % Weighted-average fair value per option granted $ 18.18 $ 15.31 $ 9.53 1 Expected term is based on historical exercise and post-vesting 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 2018 is presented below: Shares (Thousands) Weighted-Average Exercise Price Averaged Remaining Contractual Term (Years) Aggregate Intrinsic Value Outstanding at January 1, 2018 103,765 $ 97.40 Granted 4,665 $ 125.35 Exercised (12,991 ) $ 88.11 Forfeited (715 ) $ 115.25 Outstanding at December 31, 2018 94,724 $ 99.92 5.07 $ 1,101 Exercisable at December 31, 2018 81,074 $ 99.34 4.60 $ 933 The total intrinsic value (i.e., the difference between the exercise price and the market price) of options exercised during 2018 , 2017 and 2016 was $506 , $407 and $240 , respectively. During this period, the company continued its practice of issuing treasury shares upon exercise of these awards. As of December 31, 2018 , there was $53 of total unrecognized before-tax compensation cost related to nonvested share-based compensation arrangements granted under the plan. That cost is expected to be recognized over a weighted-average period of 1.6 years. At January 1, 2018 , the number of LTIP performance shares outstanding was equivalent to 3,090,793 shares. During 2018 , 1,491,141 performance shares were granted, 746,450 shares vested with cash proceeds distributed to recipients and 165,754 shares were forfeited. At December 31, 2018 , performance shares outstanding were 3,669,730 . The fair value of the liability recorded for these instruments was $258 , and was measured using the Monte Carlo simulation method. At January 1, 2018 , the number of restricted stock units outstanding was equivalent to 1,236,500 shares. During 2018, 819,769 restricted stock units were granted, 222,946 units vested with cash proceeds distributed to recipients and 95,844 units were forfeited. At December 31, 2018 , restricted stock units outstanding were 1,737,479 . The fair value of the liability recorded for the vested portion of these instruments was $125 , valued at the stock price as of December 31, 2018 . In addition, outstanding stock appreciation rights that were granted under LTIP totaled approximately 4.2 million equivalent shares as of December 31, 2018 . The fair value of the liability recorded for the vested portion of these instruments was $70 .

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2018
Retirement Benefits [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. For the company's main U.S. medical plan, 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 2018 and 2017 follows: Pension Benefits 2018 2017 Other Benefits U.S. Int’l. U.S. Int’l. 2018 2017 Change in Benefit Obligation Benefit obligation at January 1 $ 13,580 $ 5,540 $ 13,271 $ 5,169 $ 2,788 $ 2,549 Service cost 480 141 489 151 42 32 Interest cost 370 206 366 219 94 95 Plan participants' contributions — 4 — 4 71 78 Plan amendments — 23 — 1 2 — Actuarial (gain) loss (1,051 ) (239 ) 1,168 (37 ) (272 ) 266 Foreign currency exchange rate changes — (227 ) — 374 (9 ) 10 Benefits paid (1,653 ) (432 ) (1,714 ) (310 ) (237 ) (229 ) Divestitures — (196 ) — (31 ) (49 ) (13 ) Benefit obligation at December 31 11,726 4,820 13,580 5,540 2,430 2,788 Change in Plan Assets Fair value of plan assets at January 1 9,948 4,766 9,550 4,174 — — Actual return on plan assets (566 ) (9 ) 1,384 319 — — Foreign currency exchange rate changes — (221 ) — 358 — — Employer contributions 803 232 728 252 166 151 Plan participants' contributions — 4 — 4 71 78 Benefits paid (1,653 ) (432 ) (1,714 ) (310 ) (237 ) (229 ) Divestitures — (198 ) — (31 ) — — Fair value of plan assets at December 31 8,532 4,142 9,948 4,766 — — Funded status at December 31 $ (3,194 ) $ (678 ) $ (3,632 ) $ (774 ) $ (2,430 ) $ (2,788 ) Amounts recognized on the Consolidated Balance Sheet for the company’s pension and OPEB plans at December 31, 2018 and 2017 , include: Pension Benefits 2018 2017 Other Benefits U.S. Int’l. U.S. Int’l. 2018 2017 Deferred charges and other assets $ 17 $ 412 $ 21 $ 448 $ — $ — Accrued liabilities (180 ) (66 ) (188 ) (100 ) (175 ) (174 ) Noncurrent employee benefit plans (3,031 ) (1,024 ) (3,465 ) (1,122 ) (2,255 ) (2,614 ) Net amount recognized at December 31 $ (3,194 ) $ (678 ) $ (3,632 ) $ (774 ) $ (2,430 ) $ (2,788 ) Amounts recognized on a before-tax basis in “Accumulated other comprehensive loss” for the company’s pension and OPEB plans were $4,448 and $5,286 at the end of 2018 and 2017 , respectively. These amounts consisted of: Pension Benefits 2018 2017 Other Benefits U.S. Int’l. U.S. Int’l. 2018 2017 Net actuarial loss $ 3,694 $ 955 $ 4,258 $ 1,005 $ (56 ) $ 207 Prior service (credit) costs 7 104 9 94 (256 ) (287 ) Total recognized at December 31 $ 3,701 $ 1,059 $ 4,267 $ 1,099 $ (312 ) $ (80 ) The accumulated benefit obligations for all U.S. and international pension plans were $10,514 and $4,360 , respectively, at December 31, 2018 , and $12,194 and $5,009 , respectively, at December 31, 2017 . Information for U.S. and international pension plans with an accumulated benefit obligation in excess of plan assets at December 31, 2018 and 2017 , was: Pension Benefits 2018 2017 U.S. Int’l. U.S. Int’l. Projected benefit obligations $ 11,667 $ 1,277 $ 13,514 $ 1,590 Accumulated benefit obligations 10,456 1,062 12,129 1,326 Fair value of plan assets 8,456 198 9,862 413 The components of net periodic benefit cost and amounts recognized in the Consolidated Statement of Comprehensive Income for 2018 , 2017 and 2016 are shown in the table below: Pension Benefits 2018 2017 2016 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2018 2017 2016 Net Periodic Benefit Cost Service cost $ 480 $ 141 $ 489 $ 151 $ 494 $ 159 $ 42 $ 32 $ 60 Interest cost 370 206 366 219 377 261 94 95 128 Expected return on plan assets (636 ) (253 ) (597 ) (239 ) (723 ) (243 ) — — — Amortization of prior service costs (credits) 2 10 (5 ) 13 (9 ) 14 (28 ) (28 ) 14 Recognized actuarial losses 304 29 340 44 335 47 15 (5 ) 19 Settlement losses 411 33 436 2 511 6 — — — Curtailment losses (gains) — 3 — — — — — — — Total net periodic benefit cost 931 169 1,029 190 985 244 123 94 221 Changes Recognized in Comprehensive Income Net actuarial (gain) loss during period 151 12 381 (94 ) 690 55 (248 ) 284 (430 ) Amortization of actuarial loss (715 ) (62 ) (776 ) (46 ) (846 ) (53 ) (15 ) 5 (19 ) Prior service (credits) costs during period — 23 — 1 — — 3 — (345 ) Amortization of prior service (costs) credits (2 ) (13 ) 5 (13 ) 9 (14 ) 28 28 (14 ) Total changes recognized in other (566 ) (40 ) (390 ) (152 ) (147 ) (12 ) (232 ) 317 (808 ) Recognized in Net Periodic Benefit Cost and Other Comprehensive Income $ 365 $ 129 $ 639 $ 38 $ 838 $ 232 $ (109 ) $ 411 $ (587 ) Net actuarial losses recorded in “Accumulated other comprehensive loss” at December 31, 2018 , 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 13 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 2019 , the company estimates actuarial losses of $239 , $19 and $(3) 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 $290 will be recognized from “Accumulated other comprehensive loss” during 2019 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, 2018 , was approximately 4 and 8 years for U.S. and international pension plans, respectively, and 8 years for OPEB plans. During 2019 , the company estimates prior service (credits) costs of $2 , $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 2018 2017 2016 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2018 2017 2016 Assumptions used to determine benefit obligations: Discount rate 4.2 % 4.4 % 3.5 % 3.9 % 3.9 % 4.3 % 4.4 % 3.8 % 4.3 % Rate of compensation increase 4.5 % 4.0 % 4.5 % 4.0 % 4.5 % 4.5 % N/A N/A N/A Assumptions used to determine net periodic benefit cost: Discount rate for service cost 3.7 % 3.9 % 4.2 % 4.3 % 4.4 % 5.3 % 3.9 % 4.6 % 4.9 % Discount rate for interest cost 3.0 % 3.9 % 3.0 % 4.3 % 3.0 % 5.3 % 3.5 % 3.8 % 4.0 % Expected return on plan assets 6.8 % 5.5 % 6.8 % 5.5 % 7.3 % 6.3 % N/A N/A N/A Rate of compensation increase 4.5 % 4.0 % 4.5 % 4.5 % 4.5 % 4.8 % 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 2018 , the company used an expected long-term rate of return of 6.75 percent for U.S. pension plan assets, which account for 67 percent of the company’s pension plan assets. In 2017 , the company used a long-term rate of return of 6.75 percent for these plans, and in 2016 , 7.25 percent . 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. 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 2018 were 4.2 percent for the main U.S. pension plan and 4.3 percent for the main U.S. OPEB plan. The discount rates for these plans at the end of 2017 were 3.5 and 3.6 percent , respectively, while in 2016 they were 3.9 and 4.1 percent for these plans, respectively. Other Benefit Assumptions Assumed health care cost-trend rates can have a significant effect on the amounts reported for retiree health care costs. For the measurement of accumulated postretirement benefit obligation at December 31, 2018 , for the main U.S. OPEB plan, the assumed health care cost-trend rates start with 7.2 percent in 2019 and gradually decline to 4.5 percent for 2025 and beyond. For this measurement at December 31, 2017 , the assumed health care cost-trend rates started with 7.4 percent in 2018 and gradually declined to 4.5 percent for 2025 and beyond. 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 $ 12 $ (10 ) Effect on postretirement benefit obligation $ 197 $ (156 ) Plan Assets and Investment Strategy The fair value measurements of the company’s pension plans for 2018 and 2017 are on the following page: U.S. Int’l. Total Level 1 Level 2 Level 3 NAV Total Level 1 Level 2 Level 3 NAV At December 31, 2017 Equities U.S. 1 $ 1,331 $ 1,331 $ — $ — — $ 652 $ 651 $ 1 $ — $ — International 2,060 2,057 3 — — 691 691 — — — Collective Trusts/Mutual Funds 2 1,089 22 — — 1,067 204 19 4 — 181 Fixed Income Government 274 — 274 — — 296 77 219 — — Corporate 1,492 — 1,492 — — 593 — 563 30 — Bank Loans 117 — 106 11 — — — — — — Mortgage/Asset Backed 1 — 1 — — 8 — 8 — — Collective Trusts/Mutual Funds 2 1,130 — — — 1,130 1,481 — 16 — 1,465 Mixed Funds 3 — — — — — 80 1 79 — — Real Estate 4 1,096 — — — 1,096 376 — — 56 320 Alternative Investments 5 1,022 — — — 1,022 — — — — — Cash and Cash Equivalents 260 255 5 — — 366 362 4 — — Other 6 76 (2 ) 28 43 7 19 (2 ) 18 3 — Total at December 31, 2017 $ 9,948 $ 3,663 $ 1,909 $ 54 4,322 $ 4,766 $ 1,799 $ 912 $ 89 $ 1,966 At December 31, 2018 Equities U.S. 1 $ 1,110 $ 1,110 $ — $ — $ — $ 520 $ 520 $ — $ — $ — International 1,631 1,630 1 — — 521 520 — 1 — Collective Trusts/Mutual Funds 2 893 21 — — 872 152 9 — — 143 Fixed Income Government 225 — 225 — — 254 97 157 — — Corporate 1,382 — 1,382 — — 409 — 389 20 — Bank Loans 119 — 114 5 — — — — — — Mortgage/Asset Backed 1 — 1 — — 6 — 6 — — Collective Trusts/Mutual Funds 2 877 — — — 877 1,521 15 — — 1,506 Mixed Funds 3 — — — — — 74 3 71 — — Real Estate 4 1,065 — — — 1,065 378 — — 56 322 Alternative Investments 5 941 — — — 941 — — — — — Cash and Cash Equivalents 212 208 4 — — 287 277 2 — 8 Other 6 76 (4 ) 31 44 5 20 — 17 3 — Total at December 31, 2018 $ 8,532 $ 2,965 $ 1,758 $ 49 $ 3,760 $ 4,142 $ 1,441 $ 642 $ 80 $ 1,979 1 U.S. equities include investments in the company’s common stock in the amount of $9 at December 31, 2018 , and $12 at December 31, 2017 . 2 Collective Trusts/Mutual Funds for U.S. plans are entirely index funds; for International plans, they are mostly unit trust and index funds. 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 third-party appraisals that occur at least once a year for each property in the portfolio. 5 Alternative investments focus on market-neutral strategies that have a low expected correlation to traditional asset classes. 6 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 (Level 3); and investments in private-equity limited partnerships (NAV). The effects of fair value measurements using significant unobservable inputs on changes in Level 3 plan assets are outlined below: Equity Fixed Income International Corporate Bank Loans Real Estate Other Total Total at December 31, 2016 $ — $ 19 $ 11 $ 60 $ 44 $ 134 Actual Return on Plan Assets: Assets held at the reporting date — 1 — 1 — 2 Assets sold during the period — — — — — — Purchases, Sales and Settlements — 10 3 (5 ) 2 10 Transfers in and/or out of Level 3 — — (3 ) — — (3 ) Total at December 31, 2017 $ — $ 30 $ 11 $ 56 $ 46 $ 143 Actual Return on Plan Assets: Assets held at the reporting date 4 (2 ) — 13 — 15 Assets sold during the period (4 ) — — — — (4 ) Purchases, Sales and Settlements — (7 ) (4 ) (13 ) — (24 ) Transfers in and/or out of Level 3 1 — (2 ) — — (1 ) Total at December 31, 2018 $ 1 $ 21 $ 5 $ 56 $ 46 $ 129 The primary investment objectives of the pension plans are to achieve the highest rate of total return within prudent levels of risk and liquidity, to diversify and mitigate potential downside risk associated with the investments, and to provide adequate liquidity for benefit payments and portfolio management. The company’s U.S. and U.K. pension plans comprise 91 percent of the total pension assets. Both the U.S. and U.K. plans have an Investment Committee that regularly meets during the year to review the asset holdings and their returns. To assess the plans’ investment performance, long-term asset allocation policy benchmarks have been established. For the primary U.S. pension plan, the company's 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 . For the U.K. pension plan, the U.K. Board of Trustees has established the following asset allocation guidelines: Equities 25 – 45 percent , Fixed Income and Cash 40 – 75 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 2018 , the company contributed $803 and $232 to its U.S. and international pension plans, respectively. In 2019 , the company expects contributions to be approximately $700 to its U.S. plans and $200 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 $175 in 2019 ; $166 was paid in 2018 . 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 2019 $ 1,310 $ 271 $ 175 2020 $ 1,240 $ 266 $ 172 2021 $ 1,170 $ 577 $ 171 2022 $ 1,145 $ 228 $ 168 2023 $ 1,118 $ 234 $ 166 2024-2028 $ 4,972 $ 1,392 $ 795 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 $270 , $316 and $281 in 2018 , 2017 and 2016 , 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 2018 , 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, 2018 and 2017 , trust assets of $34 and $35 , 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 $1,048 , $936 and $662 in 2018 , 2017 and 2016 , 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 21 , beginning on page 80 .

Other Contingencies and Commitm

Other Contingencies and Commitments	12 Months Ended
	Dec. 31, 2018
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 16 , beginning on page 74 , 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 provisions have been made for all years under examination or subject to future examination. Guarantees The company has two guarantees to equity affiliates totaling $968 . Of this amount, $637 is associated with a financing arrangement with an equity affiliate. Over the approximate 3 -year remaining term of this guarantee, the maximum amount will be reduced as payments are made by the affiliate. The remaining amount of $331 is associated with certain payments under a terminal use agreement entered into by an equity affiliate. Over the approximate 9 -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, drill ships, 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: 2019 – $1,300 ; 2020 – $1,200 ; 2021 – $1,300 ; 2022 – $1,000 ; 2023 – $800 ; 2023 and after – $4,700 . A portion of these commitments may ultimately be shared with project partners. Total payments under the agreements were approximately $1,400 in 2018 , $1,300 in 2017 and $1,300 in 2016 . As part of the implementation of ASU 2016-02 (Topic 842) effective January 1, 2019, the company will reclassify some contracts, currently incorporated into the unconditional purchase obligations disclosure, as operating leases in first quarter 2019 results. 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, 2018 , was $1,327 . Included in this balance was $258 related to remediation activities at approximately 144 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 2018 environmental reserves balance of $1,069 , $748 is related to the company’s U.S. downstream operations, $24 to its international downstream operations, $296 to upstream operations and $1 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 2018 had a recorded liability that was material to the company’s results of operations, consolidated financial position or liquidity. Refer to Note 2 4 on page 88 for a discussion of the company’s asset retirement obligations. Other Contingencies Governmental and other entities in California and other jurisdictions have filed legal proceedings against fossil fuel producing companies, including Chevron, purporting to seek legal and equitable relief to address alleged impacts of climate change. Further such proceedings are likely to be filed by other parties. The unprecedented legal theories set forth in these proceedings entail the possibility of damages liability and injunctions against the production of all fossil fuels that, while we believe remote, could have a material adverse effect on the company’s results of operations and financial condition. Management believes that these proceedings are legally and factually meritless and detract from constructive efforts to address the important policy issues presented by climate change, and will vigorously defend against such proceedings. 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, 2018
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) both as an asset and a 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 2018 , 2017 and 2016 : 2018 2017 2016 Balance at January 1 $ 14,214 $ 14,243 $ 15,642 Liabilities incurred 96 684 204 Liabilities settled (830 ) (1,721 ) (1,658 ) Accretion expense 654 668 749 Revisions in estimated cash flows (84 ) 340 (694 ) Balance at December 31 $ 14,050 $ 14,214 $ 14,243 In the table above, the amount associated with "Revisions in estimated cash flows" in 2018 reflects decreased cost estimates to abandon wells, equipment and facilities. The long-term portion of the $14,050 balance at the end of 2018 was $12,957 .

Revenue

Revenue	12 Months Ended
	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Revenue	Revenue On January 1, 2018, Chevron adopted ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , and its related amendments using the modified retrospective transition method, which did not require the restatement of prior periods. The adoption did not result in a material change in the company’s accounting or have a material effect on the company’s financial position, including the measurement of revenue, the timing of revenue recognition and the recognition of contract assets, liabilities and related costs. The most significant change is the presentation of excise, value-added and similar taxes collected on behalf of third parties, which are no longer presented within “Sales and other operating revenue” on the Consolidated Statement of Income starting in 2018. These taxes, which totaled $7,861 in 2018 , are now netted in “Taxes other than on income” on the Consolidated Statement of Income. This change to presentation had no impact on earnings. These taxes totaled $7,189 and $6,905 in 2017 and 2016 , respectively. The company applied the optional exemption to not report any unfulfilled performance obligations related to contracts that have terms of less than one year. The amount of future revenue for unfulfilled performance obligations under long-term contracts with fixed components was insignificant for the year ended December 31, 2018 . Revenue from contracts with customers is presented in “Sales and other operating revenue” along with some activity that is accounted for outside the scope of ASC 606, which is not material to this line, on the Consolidated Statement of Income. 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. Refer to Note 13 beginning on page 66 for additional information on the company’s segmentation of revenue. Receivables related to revenue from contracts with customers are included in “Accounts and notes receivable, net” on the Consolidated Balance Sheet, net of the allowance for doubtful accounts. The net balance of these receivables was $9,779 and $10,046 at January 1, 2018 and December 31, 2018 , respectively. Other items included in “Accounts and notes receivable, net” represent amounts due from partners for their share of joint venture operating and project costs and amounts due from others, primarily related to derivatives, leases, buy/sell arrangements and product exchanges, which are accounted for outside the scope of ASC 606 . Contract assets and related costs are reflected in “Prepaid expenses and other current assets” and contract liabilities are reflected in “Accrued liabilities” and “Deferred credits and other noncurrent obligations” on the Consolidated Balance Sheet. Amounts for these items are not material to the company’s financial position.

Other Financial Information

Other Financial Information	12 Months Ended
	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Other Financial Information	Other Financial Information Earnings in 2018 included after-tax gains of approximately $630 relating to the sale of certain properties. Of this amount, approximately $365 and $265 related to downstream and upstream, respectively. Earnings in 2017 included after-tax gains of approximately $1,800 relating to the sale of certain properties, of which approximately $ 850 and $950 related to downstream and upstream assets, respectively. Earnings in 2018 included after-tax charges of approximately $2,000 for impairments and other asset write-offs related to upstream. Earnings in 2017 included after-tax charges of approximately $900 for impairments and other asset write-offs related to upstream. Other financial information is as follows: Year ended December 31 2018 2017 2016 Total financing interest and debt costs $ 921 $ 902 $ 753 Less: Capitalized interest 173 595 552 Interest and debt expense $ 748 $ 307 $ 201 Research and development expenses $ 453 $ 433 $ 476 Excess of replacement cost over the carrying value of inventories (LIFO method) $ 5,134 $ 3,937 $ 2,942 LIFO profits (losses) on inventory drawdowns included in earnings $ 26 $ (5 ) $ (88 ) Foreign currency effects * $ 611 $ (446 ) $ 58 * Includes $416 , $(45) and $1 in 2018 , 2017 and 2016 , respectively, for the company’s share of equity affiliates’ foreign currency effects. The company has $4,518 in goodwill on the Consolidated Balance Sheet, all of which is in the upstream segment and primarily related to the 2005 acquisition of Unocal. The company tested this goodwill for impairment during 2018 , and no impairment was required.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2018
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	Schedule II — Valuation and Qualifying Accounts Year ended December 31 Millions of Dollars 2018 2017 2016 Employee Termination Benefits Balance at January 1 $ 62 $ 111 $ 308 Additions (reductions) charged to expense 5 20 160 Payments (48 ) (69 ) (357 ) Balance at December 31 $ 19 $ 62 $ 111 Allowance for Doubtful Accounts Balance at January 1 $ 606 $ 487 $ 429 Additions to expense 379 128 76 Bad debt write-offs (5 ) (9 ) (18 ) Balance at December 31 $ 980 $ 606 $ 487 Deferred Income Tax Valuation Allowance * Balance at January 1 $ 16,574 $ 16,069 $ 15,412 Additions to deferred income tax expense 2,000 2,681 1,810 Reduction of deferred income tax expense (2,601 ) (2,176 ) (1,153 ) Balance at December 31 $ 15,973 $ 16,574 $ 16,069 * See also Note 16 to the Consolidated Financial Statements, beginning on page 74 .

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2018
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 circumstances change and additional information becomes known.
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. 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.
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 and Consolidated Statement of Equity.
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 are primarily stated at cost or net realizable value.
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 20 , beginning on page 79 , 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 8 , beginning on page 63 , 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 4 , on page 88 , 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. Impairments 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 annually at December 31, or more frequently if an event occurs or circumstances change that would more likely than not reduce the fair value of the reporting unit below its carrying amount.
Environmental Expenditures	Environmental Expenditures Environmental expenditures that relate to ongoing operations or to conditions caused by past operations are expensed. Expenditures that create future benefits or contribute to future revenue generation are capitalized. Liabilities related to future remediation costs are recorded when environmental assessments or cleanups or both are probable and the costs can be reasonably estimated. For crude oil, natural gas and mineral-producing properties, a liability for an ARO is made in accordance with accounting standards for asset retirement and environmental obligations. Refer to Note 2 4 , on page 88 , 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	Revenue Recognition The company accounts for each delivery order of crude oil, natural gas, petroleum and chemical products as a separate performance obligation. Revenue is recognized when the performance obligation is satisfied, which typically occurs at the point in time when control of the product transfers to the customer. Payment is generally due within 30 days of delivery. The company accounts for delivery transportation as a fulfillment cost, not a separate performance obligation, and recognizes these costs as an operating expense in the period when revenue for the related commodity is recognized. Revenue is measured as the amount the company expects to receive in exchange for transferring commodities to the customer. The company’s commodity sales are typically based on prevailing market-based prices and may include discounts and allowances. Until market prices become known under terms of the company’s contracts, the transaction price included in revenue is based on the company’s estimate of the most likely outcome. Discounts and allowances are estimated using a combination of historical and recent data trends. When deliveries contain multiple products, an observable standalone selling price is generally used to measure revenue for each product. The company includes estimates in the transaction price only to the extent that a significant reversal of revenue is not probable in subsequent periods. 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 net basis in "Taxes other than on income" on the Consolidated Statement of Income, on page 50 . 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. Prior to the adoption of ASC 606 on January 1, 2018, revenues associated with sales of crude oil, natural gas, petroleum and chemicals products, and all other sources were recorded when title passed 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 were 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 were presented on a gross basis on the Consolidated Statement of Income. On January 1, 2018, Chevron adopted ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , and its related amendments using the modified retrospective transition method, which did not require the restatement of prior periods. The adoption did not result in a material change in the company’s accounting or have a material effect on the company’s financial position, including the measurement of revenue, the timing of revenue recognition and the recognition of contract assets, liabilities and related costs. The most significant change is the presentation of excise, value-added and similar taxes collected on behalf of third parties, which are no longer presented within “Sales and other operating revenue” on the Consolidated Statement of Income starting in 2018. These taxes, which totaled $7,861 in 2018 , are now netted in “Taxes other than on income” on the Consolidated Statement of Income. This change to presentation had no impact on earnings. These taxes totaled $7,189 and $6,905 in 2017 and 2016 , respectively. The company applied the optional exemption to not report any unfulfilled performance obligations related to contracts that have terms of less than one year. The amount of future revenue for unfulfilled performance obligations under long-term contracts with fixed components was insignificant for the year ended December 31, 2018 . Revenue from contracts with customers is presented in “Sales and other operating revenue” along with some activity that is accounted for outside the scope of ASC 606, which is not material to this line, on the Consolidated Statement of Income. 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. Refer to Note 13 beginning on page 66 for additional information on the company’s segmentation of revenue. Receivables related to revenue from contracts with customers are included in “Accounts and notes receivable, net” on the Consolidated Balance Sheet, net of the allowance for doubtful accounts. The net balance of these receivables was $9,779 and $10,046 at January 1, 2018 and December 31, 2018 , respectively. Other items included in “Accounts and notes receivable, net” represent amounts due from partners for their share of joint venture operating and project costs and amounts due from others, primarily related to derivatives, leases, buy/sell arrangements and product exchanges, which are accounted for outside the scope of ASC 606 . Contract assets and related costs are reflected in “Prepaid expenses and other current assets” and contract liabilities are reflected in “Accrued liabilities” and “Deferred credits and other noncurrent obligations” on the Consolidated Balance Sheet. Amounts for these items are not material to the company’s financial position.
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 in which an employee becomes eligible to retain the award at retirement. The company’s Long-Term Incentive Plan (LTIP) awards include stock options and stock appreciation rights, which have graded vesting provisions by which one-third of each award vests on each of the first, second and third anniversaries of the date of grant. In addition, performance shares granted under the company's LTIP will vest at the end of the three -year performance period. For awards granted under the company's LTIP beginning in 2017, stock options and stock appreciation rights 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 unit awards have cliff vesting by which the total award will vest on January 31 on or after the fifth anniversary of the grant date, subject to adjustment upon termination pursuant to the satisfaction of certain criteria. The company amortizes these awards on a straight-line basis.
New Accounting Standards	New Accounting Standards Revenue Recognition (Topic 606): Revenue from Contracts with Customers On January 1, 2018, Chevron adopted ASU 2014-09 and its related amendments using the modified retrospective transition method, which did not require the restatement of prior periods. The impact of the adoption of the standard did not have a material effect on the company’s consolidated financial statements. For additional information on the company’s revenue, refer to Note 25 beginning on page 88 . Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20) On January 1, 2018, the company adopted ASU 2017-05, which provides clarification regarding the guidance on accounting for the derecognition of nonfinancial assets. The adoption of the standard had no impact on the company’s consolidated financial statements. Compensation - Retirement Benefits (Topic 715) Effective January 1, 2018, Chevron adopted ASU 2017-07 on a retrospective basis. The standard requires the disaggregation of the service cost component from the other components of net periodic benefit cost and allows only the service cost component of net benefit cost to be eligible for capitalization. The effects of retrospective adoption on the Consolidated Statement of Income for 2017 and 2016 were to move $310 and $366 from "Operating expenses" and $338 and $379 from "Selling, general and administrative expenses" to "Other components of net periodic benefits cost," respectively. Statement of Cash Flows (Topic 230) Classification of Certain Cash Receipts and Cash Payments Effective January 1, 2018, Chevron adopted ASU 2016-15 on a retrospective basis. The standard provides clarification on how certain cash receipts and cash payments are presented and classified on the Consolidated Statement of Cash Flows. The adoption of this ASU did not have a material impact on the company's Consolidated Statement of Cash Flows. For additional information, refer to Note 3 beginning on page 59 . Statement of Cash Flows (Topic 230) Restricted Cash Effective January 1, 2018, Chevron adopted ASU 2016-18 on a retrospective basis. The standard requires an entity to explain the changes in the total of cash, cash equivalents, restricted cash and restricted cash equivalents on the Consolidated Statement of Cash Flows and to provide a reconciliation to the Consolidated Balance Sheet when the cash, cash equivalents, restricted cash and restricted cash equivalents are not separately presented or are presented in more than one line item on the Consolidated Balance Sheet. The company’s restricted cash balances are now included in the beginning and ending balances on the Consolidated Statement of Cash Flows. For additional information, refer to Note 3 beginning on page 59 . Income Statement - Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income In fourth quarter 2018, the company elected to early adopt ASU 2018-02, which permits the reclassification of stranded tax effects in accumulated other comprehensive income as a result of U.S. tax reform. Accordingly, Chevron reclassified $562 from "Accumulated other comprehensive losses" to "Retained earnings" associated with the reduction of the U.S. statutory tax rate from 35 percent to 21 percent. In accordance with its accounting policy, the company releases stranded income tax effects from accumulated other comprehensive income in the period the underlying activity ceases to exist. ASU 2018-02 allowed for the reclassification of stranded tax effects as a result of the change in tax rates due to U.S. tax reform to be recorded upon adoption of the ASU, rather than at the actual date that the underlying activity ceases to exist. For additional detail, refer to Note 2 beginning on page 58 . Leases (Topic 842) In February 2016, the Financial Accounting Standards Board (FASB) issued ASU 2016-02, which became effective for the company January 1, 2019. The standard requires that lessees present right-of-use assets and lease liabilities on the Consolidated Balance Sheet. The company plans to elect the short-term lease exception provided for in the standard and therefore will only recognize right-of-use assets and lease liabilities for leases with a term greater than one year. The company further intends to elect the option to apply the transition provisions of the new standard at the adoption date instead of the earliest comparative period presented in the financial statements. The company plans to elect the package of practical expedients to not re-evaluate existing lease contracts or lease classifications and therefore will not make changes to those leases already recognized on the Consolidated Balance Sheet under ASC 840 until the leases are fully amortized, amended, or modified. In addition, the company will not reassess initial direct costs for any existing leases. The company intends to apply the land easement practical expedient. Chevron plans to elect the practical expedient to not separate non-lease components from lease components for most asset classes except for certain asset classes that have significant non-lease (i.e., service) components in addition to the lease component. The company will reclassify some contracts, currently not classified as leases, as operating leases under the new standard. The company completed accounting policy and disclosure updates and system implementation necessary to meet the standard's requirements. The company does not expect the adoption of the ASU to have a material impact on finance leases, which are currently referred to as capital leases. The company estimates that the operating lease right-of-use assets and lease liabilities on the Consolidated Balance Sheet are approximately $4 billion , as of January 1, 2019. The company expects the implementation of the standard will have a minimal impact on the Consolidated Statement of Income and Consolidated Statement of Cash Flows. 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.
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. 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 are not allocated to the operating segments. However, operating segments are billed for the direct use of corporate services
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 _2

Changes in Accumulated Other Comprehensive Losses (Tables)	12 Months Ended
	Dec. 31, 2018
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 ended December 31, 2018 , are reflected in the table below. Currency Translation Adjustments Unrealized Holding Gains (Losses) on Securities Derivatives Defined Benefit Plans Total Balance at December 31, 2015 $ (140 ) $ (29 ) $ (2 ) $ (4,120 ) $ (4,291 ) Components of Other Comprehensive Income (Loss) 1 : Before Reclassifications (22 ) 27 — (161 ) (156 ) Reclassifications 2 — — — 604 604 Net Other Comprehensive Income (Loss) (22 ) 27 — 443 448 Balance at December 31, 2016 $ (162 ) $ (2 ) $ (2 ) $ (3,677 ) $ (3,843 ) Components of Other Comprehensive Income (Loss) 1 : Before Reclassifications 57 (3 ) — (310 ) (256 ) Reclassifications 2 — — — 510 510 Net Other Comprehensive Income (Loss) 57 (3 ) — 200 254 Balance at December 31, 2017 $ (105 ) $ (5 ) $ (2 ) $ (3,477 ) $ (3,589 ) Components of Other Comprehensive Income (Loss) 1 : Before Reclassifications (19 ) (5 ) — 28 4 Reclassifications 2 — — — 603 603 Net Other Comprehensive Income (Loss) (19 ) (5 ) — 631 607 Stranded Tax Reclassification to Retained Earnings 3 — — — (562 ) (562 ) Balance at December 31, 2018 $ (124 ) $ (10 ) $ (2 ) $ (3,408 ) $ (3,544 ) 1 All amounts are net of tax. 2 Refer to Note 22 beginning on page 81 , for reclassified components totaling $779 that are included in employee benefit costs for the year ended December 31, 2018 . Related income taxes for the same period, totaling $176 , are reflected in Income Tax Expense on the Consolidated Statement of Income. All other reclassified amounts were insignificant. 3 Stranded tax reclassification to retained earnings per ASU 2018-02. Refer to Note 4 , " New Accounting Standards " on page 60 .

Information Relating to the C_2

Information Relating to the Consolidated Statement of Cash Flows (Tables)	12 Months Ended
	Dec. 31, 2018
Supplemental Cash Flow Elements [Abstract]
Schedule of information relating to the consolidated statement of cash flows	Year ended December 31 2018 2017 2016 Net decrease (increase) in operating working capital was composed of the following: Decrease (increase) in accounts and notes receivable $ 437 $ (915 ) $ (2,121 ) Decrease (increase) in inventories (424 ) (267 ) 603 Decrease (increase) in prepaid expenses and other current assets 1 (149 ) 173 829 Increase (decrease) in accounts payable and accrued liabilities 1 (494 ) 998 366 Increase (decrease) in income and other taxes payable (88 ) 531 (4 ) Net decrease (increase) in operating working capital $ (718 ) $ 520 $ (327 ) Net cash provided by operating activities includes the following cash payments: Interest on debt (net of capitalized interest) $ 736 $ 265 $ 158 Income taxes 4,748 3,132 1,935 Proceeds and deposits related to asset sales and returns of investment consisted of the following gross amounts: Proceeds and deposits related to asset sales 1 $ 2,000 $ 4,930 $ 3,154 Returns of investment from equity affiliates 2 392 166 322 Proceeds and deposits related to asset sales and returns of investment $ 2,392 $ 5,096 $ 3,476 Net maturities (investments) of time deposits consisted of the following gross amounts: Investments in time deposits $ (950 ) $ — $ — Maturities of time deposits — — — Net maturities of (investments in) time deposits $ (950 ) $ — $ — Net sales (purchases) of marketable securities consisted of the following gross amounts: Marketable securities purchased $ (51 ) $ (3 ) $ (9 ) Marketable securities sold — 7 306 Net sales (purchases) of marketable securities $ (51 ) $ 4 $ 297 Net repayment (borrowing) of loans by equity affiliates: Borrowing of loans by equity affiliates $ — $ (142 ) $ (2,341 ) Repayment of loans by equity affiliates 111 126 307 Net repayment (borrowing) of loans by equity affiliates $ 111 $ (16 ) $ (2,034 ) Net borrowings (repayments) of short-term obligations consisted of the following gross and net amounts: Proceeds from issuances of short-term obligations $ 2,486 $ 5,051 $ 14,778 Repayments of short-term obligations (4,136 ) (8,820 ) (12,558 ) Net borrowings (repayments) of short-term obligations with three months or less maturity 3,671 (1,373 ) (90 ) Net borrowings (repayments) of short-term obligations $ 2,021 $ (5,142 ) $ 2,130 1 2017 and 2016 adjusted to conform to ASU 2016-18. 2 Per ASU 2016-15. The table below quantifies the beginning and ending balances of restricted cash and restricted cash equivalents in the Consolidated Balance Sheet: Year ended December 31 2018 2017 2016 2015 Cash and cash equivalents $ 9,342 $ 4,813 $ 6,988 $ 11,022 Restricted cash included in "Prepaid expenses and other current assets" 341 405 488 196 Restricted cash included in "Deferred charges and other assets" 798 725 938 904 Total cash, cash equivalents and restricted cash $ 10,481 $ 5,943 $ 8,414 $ 12,122
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 2018 2017 2016 Additions to properties, plant and equipment * $ 13,384 $ 13,222 $ 17,742 Additions to investments 65 25 55 Current-year dry hole expenditures 344 157 313 Payments for other liabilities and assets, net (1 ) — (1 ) Capital expenditures 13,792 13,404 18,109 Expensed exploration expenditures 523 666 544 Assets acquired through capital lease obligations and other financing obligations 75 8 5 Capital and exploratory expenditures, excluding equity affiliates 14,390 14,078 18,658 Company's share of expenditures by equity affiliates 5,716 4,743 3,770 Capital and exploratory expenditures, including equity affiliates $ 20,106 $ 18,821 $ 22,428 * Excludes non-cash additions of $25 in 2018 , $1,183 in 2017 and $56 in 2016 .

Lease Commitments (Tables)

Lease Commitments (Tables)	12 Months Ended
	Dec. 31, 2018
Leases [Abstract]
Schedule of capitalized leased assets	Details of the capitalized leased assets are below: At December 31 2018 2017 Upstream $ 719 $ 678 Downstream 99 99 All Other — — Total 818 777 Less: Accumulated amortization 617 515 Net capitalized leased assets $ 201 $ 262
Rental expenses incurred for operating leases	Rental expenses incurred for operating leases during 2018 , 2017 and 2016 were as follows: Year ended December 31 2018 2017 2016 Minimum rentals $ 820 $ 726 $ 943 Contingent rentals 1 1 2 Total 821 727 945 Less: Sublease rental income 5 6 7 Net rental expense $ 816 $ 721 $ 938
Estimated future minimum lease payments (net of noncancelable sublease rentals) under operating and capital leases	At December 31, 2018 , 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 2019 $ 540 $ 30 2020 492 22 2021 378 17 2022 242 16 2023 166 16 Thereafter 341 132 Total $ 2,159 $ 233 Less: Amounts representing interest and executory costs $ (88 ) Net present values 145 Less: Capital lease obligations included in short-term debt (18 ) Long-term capital lease obligations $ 127 * Excluded from the table is an executed but not-yet-commenced capital lease with payments of $14, $15, $22, $21, $21, and $219 for 2019, 2020, 2021, 2022, 2023, and thereafter, respectively.

Summarized Financial Data - C_2

Summarized Financial Data - Chevron U.S.A. Inc. (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2016 Sales and other operating revenues $ 125,076 $ 104,054 $ 83,715 Total costs and other deductions 121,351 103,904 87,429 Net income (loss) attributable to CUSA 4,334 4,842 (1,177 )
Summarized Financial Data and its Subsidiary	At December 31 2018 2017 Current assets $ 12,819 $ 12,163 Other assets 55,814 54,994 Current liabilities 16,376 17,379 Other liabilities 12,906 12,541 Total CUSA net equity $ 39,351 $ 37,237 Memo: Total debt $ 3,049 $ 3,056

Summarized Financial Data - T_2

Summarized Financial Data - Tengizchevroil LLP (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2016 Sales and other operating revenues $ 17,260 $ 13,363 $ 10,460 Costs and other deductions 7,446 6,507 6,822 Net income attributable to TCO 6,908 4,841 2,563
Summarized Financial Data and its Affiliate	At December 31 2018 2017 Current assets $ 2,374 $ 4,239 Other assets 34,727 26,411 Current liabilities 3,069 2,517 Other liabilities 6,357 6,266 Total TCO net equity $ 27,675 $ 21,867

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2018
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 December 31, 2018 At December 31, 2017 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Marketable securities $ 53 $ 53 $ — $ — $ 9 $ 9 $ — $ — Derivatives 283 185 98 — 22 — 22 — Total assets at fair value $ 336 $ 238 $ 98 $ — $ 31 $ 9 $ 22 $ — Derivatives 12 — 12 — 124 78 46 — Total liabilities at fair value $ 12 $ — $ 12 $ — $ 124 $ 78 $ 46 $ —
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 2018 Total Level 1 Level 2 Level 3 Year 2017 Properties, plant and equipment, net (held and used) $ 102 $ — $ 62 $ 40 $ 97 $ 603 $ — $ — $ 603 $ 658 Properties, plant and equipment, net (held for sale) 1,694 — 1,273 421 638 1,378 — 1,378 — 363 Investments and advances 81 — 20 61 69 28 — 1 27 26 Total nonrecurring assets at fair value $ 1,877 $ — $ 1,355 $ 522 $ 804 $ 2,009 $ — $ 1,379 $ 630 $ 1,047

Financial and Derivative Inst_2

Financial and Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 2017 Commodity Accounts and notes receivable, net $ 279 $ 22 Commodity Long-term receivables, net 4 — Total assets at fair value $ 283 $ 22 Commodity Accounts payable $ 12 $ 122 Commodity Deferred credits and other noncurrent obligations — 2 Total liabilities at fair value $ 12 $ 124
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 2018 2017 2016 Commodity Sales and other operating revenues $ 135 $ (105 ) $ (269 ) Commodity Purchased crude oil and products (33 ) (9 ) (31 ) Commodity Other income 3 (2 ) — $ 105 $ (116 ) $ (300 )
Consolidated Balance Sheet: The Effect of Netting Derivative Assets	The table below represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at December 31, 2018 and December 31, 2017 . Consolidated Balance Sheet: The Effect of Netting Derivative Assets and Liabilities Gross Amounts Recognized Gross Amounts Offset Net Amounts Presented Gross Amounts Not Offset Net Amounts At December 31, 2018 Derivative Assets $ 3,685 $ 3,402 $ 283 $ — $ 283 Derivative Liabilities $ 3,414 $ 3,402 $ 12 $ — $ 12 At December 31, 2017 Derivative Assets $ 1,169 $ 1,147 $ 22 $ — $ 22 Derivative Liabilities $ 1,271 $ 1,147 $ 124 $ — $ 124
Consolidated Balance Sheet: The Effect of Netting Derivative Liabilities	The table below represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at December 31, 2018 and December 31, 2017 . Consolidated Balance Sheet: The Effect of Netting Derivative Assets and Liabilities Gross Amounts Recognized Gross Amounts Offset Net Amounts Presented Gross Amounts Not Offset Net Amounts At December 31, 2018 Derivative Assets $ 3,685 $ 3,402 $ 283 $ — $ 283 Derivative Liabilities $ 3,414 $ 3,402 $ 12 $ — $ 12 At December 31, 2017 Derivative Assets $ 1,169 $ 1,147 $ 22 $ — $ 22 Derivative Liabilities $ 1,271 $ 1,147 $ 124 $ — $ 124

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2018
Earnings Per Share [Abstract]
Computation of basic and diluted EPS	The table below sets forth the computation of basic and diluted EPS: Year ended December 31 2018 2017 2016 Basic EPS Calculation Earnings available to common stockholders - Basic 1 $ 14,824 $ 9,195 $ (497 ) Weighted-average number of common shares outstanding 2 1,897 1,882 1,872 Add: Deferred awards held as stock units 1 1 1 Total weighted-average number of common shares outstanding 1,898 1,883 1,873 Earnings per share of common stock - Basic $ 7.81 $ 4.88 $ (0.27 ) Diluted EPS Calculation Earnings available to common stockholders - Diluted 1 $ 14,824 $ 9,195 $ (497 ) Weighted-average number of common shares outstanding 2 1,897 1,882 1,872 Add: Deferred awards held as stock units 1 1 1 Add: Dilutive effect of employee stock-based awards 16 15 — Total weighted-average number of common shares outstanding 1,914 1,898 1,873 Earnings per share of common stock - Diluted $ 7.74 $ 4.85 $ (0.27 ) 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 Geogra_2

Operating Segments and Geographic Data (Tables)	12 Months Ended
	Dec. 31, 2018
Segment Reporting [Abstract]
Segment Earnings	Earnings by major operating area are presented in the following table: Year ended December 31 2018 2017 2016 Upstream United States $ 3,278 $ 3,640 $ (2,054 ) International 10,038 4,510 (483 ) Total Upstream 13,316 8,150 (2,537 ) Downstream United States 2,103 2,938 1,307 International 1,695 2,276 2,128 Total Downstream 3,798 5,214 3,435 Total Segment Earnings 17,114 13,364 898 All Other Interest expense (713 ) (264 ) (168 ) Interest income 137 60 58 Other (1,714 ) (3,965 ) (1,285 ) Net Income (Loss) Attributable to Chevron Corporation $ 14,824 $ 9,195 $ (497 )
Segment Assets	Assets at year-end 2018 and 2017 are as follows: At December 31 2018 2017 Upstream United States $ 42,594 $ 40,770 International 153,861 159,612 Goodwill 4,518 4,531 Total Upstream 200,973 204,913 Downstream United States 23,866 23,202 International 15,622 17,434 Total Downstream 39,488 40,636 Total Segment Assets 240,461 245,549 All Other United States 5,100 4,938 International 8,302 3,319 Total All Other 13,402 8,257 Total Assets – United States 71,560 68,910 Total Assets – International 177,785 180,365 Goodwill 4,518 4,531 Total Assets $ 253,863 $ 253,806
Segment Sales and Other Operating Revenues	Year ended December 31 1 2018 2017 2016 Upstream United States $ 8,926 $ 3,901 $ 3,148 Intersegment 13,965 9,341 7,217 Total United States 22,891 13,242 10,365 International 24,143 17,209 13,262 Intersegment 13,679 11,471 9,518 Total International 37,822 28,680 22,780 Total Upstream 60,713 41,922 33,145 Downstream United States 56,634 48,728 40,366 Excise and similar taxes 2 — 4,398 4,335 Intersegment 2,742 14 16 Total United States 59,376 53,140 44,717 International 68,963 57,438 46,388 Excise and similar taxes 2 — 2,791 2,570 Intersegment 1,132 1,166 1,068 Total International 70,095 61,395 50,026 Total Downstream 129,471 114,535 94,743 All Other United States 236 208 145 Intersegment 786 814 960 Total United States 1,022 1,022 1,105 International — 1 1 Intersegment 22 25 36 Total International 22 26 37 Total All Other 1,044 1,048 1,142 Segment Sales and Other Operating Revenues United States 83,289 67,404 56,187 International 107,939 90,101 72,843 Total Segment Sales and Other Operating Revenues 191,228 157,505 129,030 Elimination of intersegment sales (32,326 ) (22,831 ) (18,815 ) Total Sales and Other Operating Revenues $ 158,902 $ 134,674 $ 110,215 1 Other than the United States, no other country accounted for 10 percent or more of the company’s Sales and Other Operating Revenues. 2 Netted in "Taxes other than on income" beginning in 2018 in accordance with ASU 2014-09. Refer to Note 25 beginning on page 88.
Segment income tax expense	Segment income tax expense for the years 2018 , 2017 and 2016 is as follows: Year ended December 31 2018 2017 2016 Upstream United States $ 811 $ (3,538 ) $ (1,172 ) International 4,687 2,249 166 Total Upstream 5,498 (1,289 ) (1,006 ) Downstream United States 534 (419 ) 503 International 328 650 484 Total Downstream 862 231 987 All Other (645 ) 1,010 (1,710 ) Total Income Tax Expense (Benefit) $ 5,715 $ (48 ) $ (1,729 )

Investments and Advances (Table

Investments and Advances (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2018 2017 2016 Upstream Tengizchevroil $ 16,017 $ 13,121 $ 3,614 $ 2,581 $ 1,380 Petropiar 1,361 1,152 317 175 326 Petroboscan 1,315 1,080 357 154 (133 ) Caspian Pipeline Consortium 1,022 1,151 170 155 145 Angola LNG Limited 2,496 2,625 172 27 (282 ) Other 1,541 1,714 19 104 (193 ) Total Upstream 23,752 20,843 4,649 3,196 1,243 Downstream Chevron Phillips Chemical Company LLC 6,218 6,200 1,034 723 840 GS Caltex Corporation 3,924 3,826 373 290 373 Other 1,383 1,251 273 230 209 Total Downstream 11,525 11,277 1,680 1,243 1,422 All Other Other (16 ) (15 ) (2 ) (1 ) (4 ) Total equity method 35,261 $ 32,105 $ 6,327 $ 4,438 $ 2,661 Other non-equity method investments 285 392 Total investments and advances $ 35,546 $ 32,497 Total United States $ 7,500 $ 7,582 $ 1,033 $ 788 $ 802 Total International $ 28,046 $ 24,915 $ 5,294 $ 3,650 $ 1,859
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 $3,402 , $3,853 and $3,535 at December 31, 2018 , 2017 and 2016 , respectively. Affiliates Chevron Share Year ended December 31 2018 2017 2016 2018 2017 2016 Total revenues $ 84,469 $ 70,744 $ 59,253 $ 40,679 $ 33,460 $ 27,787 Income before income tax expense 16,693 13,487 6,587 6,755 5,712 3,670 Net income attributable to affiliates 13,321 10,751 5,127 6,384 4,468 2,876 At December 31 Current assets $ 32,657 $ 33,883 $ 33,406 $ 12,813 $ 13,568 $ 13,743 Noncurrent assets 87,614 82,261 75,258 36,369 32,643 28,854 Current liabilities 26,006 26,873 24,793 9,843 10,201 8,996 Noncurrent liabilities 20,000 21,447 22,671 4,446 4,224 4,255 Total affiliates' net equity $ 74,265 $ 67,824 $ 61,200 $ 34,893 $ 31,786 $ 29,346

Taxes (Tables)

Taxes (Tables)	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Taxes on income	Income Taxes Year ended December 31 2018 2017 2016 Income tax expense (benefit) U.S. federal Current $ (181 ) $ (382 ) $ (623 ) Deferred 738 (2,561 ) (1,558 ) State and local Current 183 (97 ) (15 ) Deferred (16 ) 66 (121 ) Total United States 724 (2,974 ) (2,317 ) International Current 4,662 3,634 2,744 Deferred 329 (708 ) (2,156 ) Total International 4,991 2,926 588 Total income tax expense (benefit) $ 5,715 $ (48 ) $ (1,729 )
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: 2018 2017 2016 Income (loss) before income taxes United States $ 4,730 $ (441 ) $ (4,317 ) International 15,845 9,662 2,157 Total income (loss) before income taxes 20,575 9,221 (2,160 ) Theoretical tax (at U.S. statutory rate of 21% - 2018, 35% - 2017 & 2016) 4,321 3,227 (756 ) Effect of U.S. tax reform (26 ) (2,020 ) — Equity affiliate accounting effect (1,526 ) (1,373 ) (704 ) Effect of income taxes from international operations * 3,132 (130 ) 608 State and local taxes on income, net of U.S. federal income tax benefit 162 39 (44 ) Prior year tax adjustments, claims and settlements (51 ) (39 ) (349 ) Tax credits (163 ) (199 ) (188 ) Other U.S. * (134 ) 447 (296 ) Total income tax expense (benefit) $ 5,715 $ (48 ) $ (1,729 ) Effective income tax rate 27.8 % (0.5 )% 80.0 % * Includes one-time tax costs (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 2018 2017 Deferred tax liabilities Properties, plant and equipment $ 20,159 $ 19,869 Investments and other 4,943 4,796 Total deferred tax liabilities 25,102 24,665 Deferred tax assets Foreign tax credits (10,536 ) (11,872 ) Asset retirement obligations/environmental reserves (5,328 ) (5,511 ) Employee benefits (2,787 ) (3,129 ) Deferred credits (1,373 ) (1,769 ) Tax loss carryforwards (4,948 ) (5,463 ) Other accrued liabilities (595 ) (842 ) Inventory (505 ) (336 ) Miscellaneous (3,481 ) (2,415 ) Total deferred tax assets (29,553 ) (31,337 ) Deferred tax assets valuation allowance 15,973 16,574 Total deferred taxes, net $ 11,522 $ 9,902
Classification of deferred taxes	At December 31, 2018 and 2017 , deferred taxes were classified on the Consolidated Balance Sheet as follows: At December 31 2018 2017 Deferred charges and other assets $ (4,399 ) $ (4,750 ) Noncurrent deferred income taxes 15,921 14,652 Total deferred income taxes, net $ 11,522 $ 9,902
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, 2018 , 2017 and 2016 . 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. 2018 2017 2016 Balance at January 1 $ 4,828 $ 3,031 $ 3,042 Foreign currency effects (6 ) 43 1 Additions based on tax positions taken in current year 239 1,853 245 Additions for tax positions taken in prior years 153 1,166 181 Reductions for tax positions taken in prior years (131 ) (90 ) (390 ) Settlements with taxing authorities in current year (13 ) (1,173 ) (36 ) Reductions as a result of a lapse of the applicable statute of limitations — (2 ) (12 ) Balance at December 31 $ 5,070 $ 4,828 $ 3,031
Taxes other than on income	Taxes Other Than on Income Year ended December 31 2018 2017 2016 United States Excise and similar taxes on products and merchandise* $ 4,830 $ 4,398 $ 4,335 Consumer excise taxes collected on behalf of third parties* (4,830 ) — — Import duties and other levies 15 11 9 Property and other miscellaneous taxes 1,577 1,824 1,680 Payroll taxes 246 241 252 Taxes on production 325 206 159 Total United States 2,163 6,680 6,435 International Excise and similar taxes on products and merchandise* 3,031 2,791 2,570 Consumer excise taxes collected on behalf of third parties* (3,031 ) — — Import duties and other levies 37 45 33 Property and other miscellaneous taxes 2,370 2,563 2,379 Payroll taxes 132 137 145 Taxes on production 165 115 106 Total International 2,704 5,651 5,233 Total taxes other than on income $ 4,867 $ 12,331 $ 11,668 * Beginning in 2018, these taxes are netted in "Taxes other than on income" in accordance with ASU 2014-09. Refer to Note 25, "Revenue" beginning on page 88.

Properties, Plant and Equipme_2

Properties, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 2017 2016 2018 2017 2016 2018 2017 2016 2018 2017 2016 Upstream United States $ 88,155 $ 84,602 $ 83,929 $ 39,526 $ 38,722 $ 39,710 $ 6,434 $ 4,995 $ 4,432 $ 5,328 $ 5,527 $ 6,576 International 215,329 224,211 214,557 113,603 123,191 125,502 4,865 7,934 12,084 12,726 12,096 11,247 Total Upstream 303,484 308,813 298,486 153,129 161,913 165,212 11,299 12,929 16,516 18,054 17,623 17,823 Downstream United States 24,685 23,598 22,795 10,838 10,346 10,196 1,259 907 528 751 753 956 International 7,237 7,094 9,350 3,023 3,074 4,094 278 306 375 282 282 332 Total Downstream 31,922 30,692 32,145 13,861 13,420 14,290 1,537 1,213 903 1,033 1,035 1,288 All Other United States 4,667 4,798 5,263 2,186 2,341 2,635 224 218 198 320 677 328 International 171 182 183 31 38 49 6 4 6 12 14 18 Total All Other 4,838 4,980 5,446 2,217 2,379 2,684 230 222 204 332 691 346 Total United States 117,507 112,998 111,987 52,550 51,409 52,541 7,917 6,120 5,158 6,399 6,957 7,860 Total International 222,737 231,487 224,090 116,657 126,303 129,645 5,149 8,244 12,465 13,020 12,392 11,597 Total $ 340,244 $ 344,485 $ 336,077 $ 169,207 $ 177,712 $ 182,186 $ 13,066 $ 14,364 $ 17,623 $ 19,419 $ 19,349 $ 19,457 1 Other than the United States and Australia, no other country accounted for 10 percent or more of the company’s net properties, plant and equipment (PP&E) in 2018 . Australia had PP&E of $53,768 , $55,514 and $53,962 in 2018 , 2017 and 2016 , respectively. 2 Net of dry hole expense related to prior years’ expenditures of $343 , $42 and $175 in 2018 , 2017 and 2016 , respectively. 3 Depreciation expense includes accretion expense of $654 , $668 and $749 in 2018 , 2017 and 2016 , respectively, and impairments of $735 , $1,021 and $3,186 in 2018 , 2017 and 2016 , respectively.

Short-Term Debt (Tables)

Short-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Short-Term Debt	At December 31 2018 2017 Commercial paper 1 $ 7,503 $ 5,379 Notes payable to banks and others with originating terms of one year or less 28 — Current maturities of long-term debt 2 4,999 6,720 Current maturities of long-term capital leases 18 15 Redeemable long-term obligations Long-term debt 3,078 3,078 Capital leases — — Subtotal 15,626 15,192 Reclassified to long-term debt (9,900 ) (10,000 ) Total short-term debt $ 5,726 $ 5,192 1 Weighted-average interest rates at December 31, 2018 and 2017, were 2.43 percent and 1.30 percent, respectively. 2 Net of unamortized discounts and issuance costs: $1 in 2018 and $2 in 2017.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Long-term debt outstanding	The company’s long-term debt outstanding at year-end 2018 and 2017 was as follows: At December 31 2018 2017 Principal Principal 3.191% notes due 2023 $ 2,250 $ 2,250 2.954% notes due 2026 2,250 2,250 2.355% notes due 2022 2,000 2,000 1.961% notes due 2020 1,750 1,750 4.950% notes due 2019 1,500 1,500 1.561% notes due 2019 1,350 1,350 2.100% notes due 2021 1,350 1,350 2.419% notes due 2020 1,250 1,250 2.427% notes due 2020 1,000 1,000 2.895% notes due 2024 1,000 1,000 Floating rate notes due 2019 (2.905%) 1 850 850 2.193% notes due 2019 750 750 2.566% notes due 2023 750 750 3.326% notes due 2025 750 750 2.498% notes due 2022 700 700 2.411% notes due 2022 700 700 Floating rate notes due 2021 (3.313%) 1 650 650 Floating rate notes due 2022 (3.245%) 1 650 650 1.991% notes due 2020 600 600 1.686% notes due 2019 550 550 Floating rate notes due 2020 (2.948%) 2 400 400 3.400% loan 3 218 — 8.625% debentures due 2032 147 147 8.625% debentures due 2031 108 108 8.000% debentures due 2032 75 75 9.750% debentures due 2020 54 54 8.875% debentures due 2021 40 40 Medium-term notes, maturing from 2021 to 2038 (6.629%) 1 38 38 1.718% notes due 2018 — 2,000 1.365% notes due 2018 — 1,750 Floating rate notes due 2018 — 1,650 1.790% notes due 2018 — 1,250 Amortizing bank loan due 2018 — 72 Total including debt due within one year 23,730 30,234 Debt due within one year (5,000 ) (6,722 ) Reclassified from short-term debt 9,900 10,000 Unamortized discounts and debt issuance costs (24 ) (35 ) Capital lease obligations 4 127 94 Total long-term debt $ 28,733 $ 33,571 1 Weighted-average interest rate at December 31, 2018 . 2 Interest rate at December 31, 2018. 3 Maturity date is conditional upon the occurrence of certain events. 2021 is the earliest period in which the loan may become payable. 4 For details on capital lease obligations, see Note 5 beginning on page 62.

Accounting for Suspended Expl_2

Accounting for Suspended Exploratory Wells (Tables)	12 Months Ended
	Dec. 31, 2018
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, 2018 : 2018 2017 2016 Beginning balance at January 1 $ 3,702 $ 3,540 $ 3,312 Additions to capitalized exploratory well costs pending the determination of proved reserves 207 323 465 Reclassifications to wells, facilities and equipment based on the determination of proved reserves (13 ) (113 ) (119 ) Capitalized exploratory well costs charged to expense (333 ) (39 ) (118 ) Other reductions * — (9 ) — Ending balance at December 31 $ 3,563 $ 3,702 $ 3,540 * 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 2018 2017 2016 Exploratory well costs capitalized for a period of one year or less $ 202 $ 307 $ 445 Exploratory well costs capitalized for a period greater than one year 3,361 3,395 3,095 Balance at December 31 $ 3,563 $ 3,702 $ 3,540 Number of projects with exploratory well costs that have been capitalized for a period greater than one year * 30 32 35 * Certain projects have multiple wells or fields or both.
Aging of Costs on Well and Project Basis	The $3,361 of suspended well costs capitalized for a period greater than one year as of December 31, 2018 , represents 153 exploratory wells in 30 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 1998-2007 $ 410 31 2008-2012 1,076 61 2013-2017 1,875 61 Total $ 3,361 153 Aging based on drilling completion date of last suspended well in project: Amount Number of projects 2003-2010 $ 338 5 2011-2014 894 10 2015-2018 2,129 15 Total $ 3,361 30

Stock Options and Other Share_2

Stock Options and Other Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 , 2017 and 2016 were measured on the date of grant using the Black-Scholes option-pricing model, with the following weighted-average assumptions: Year ended December 31 2018 2017 2016 Expected term in years 1 6.5 6.3 6.3 Volatility 2 21.2 % 21.7 % 21.7 % Risk-free interest rate based on zero coupon U.S. treasury note 2.6 % 2.2 % 1.6 % Dividend yield 3.8 % 4.2 % 4.5 % Weighted-average fair value per option granted $ 18.18 $ 15.31 $ 9.53 1 Expected term is based on historical exercise and post-vesting 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 2018 is presented below: Shares (Thousands) Weighted-Average Exercise Price Averaged Remaining Contractual Term (Years) Aggregate Intrinsic Value Outstanding at January 1, 2018 103,765 $ 97.40 Granted 4,665 $ 125.35 Exercised (12,991 ) $ 88.11 Forfeited (715 ) $ 115.25 Outstanding at December 31, 2018 94,724 $ 99.92 5.07 $ 1,101 Exercisable at December 31, 2018 81,074 $ 99.34 4.60 $ 933

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2018
Retirement Benefits [Abstract]
Funded status of pension and other postretirement benefit plans	The funded status of the company’s pension and OPEB plans for 2018 and 2017 follows: Pension Benefits 2018 2017 Other Benefits U.S. Int’l. U.S. Int’l. 2018 2017 Change in Benefit Obligation Benefit obligation at January 1 $ 13,580 $ 5,540 $ 13,271 $ 5,169 $ 2,788 $ 2,549 Service cost 480 141 489 151 42 32 Interest cost 370 206 366 219 94 95 Plan participants' contributions — 4 — 4 71 78 Plan amendments — 23 — 1 2 — Actuarial (gain) loss (1,051 ) (239 ) 1,168 (37 ) (272 ) 266 Foreign currency exchange rate changes — (227 ) — 374 (9 ) 10 Benefits paid (1,653 ) (432 ) (1,714 ) (310 ) (237 ) (229 ) Divestitures — (196 ) — (31 ) (49 ) (13 ) Benefit obligation at December 31 11,726 4,820 13,580 5,540 2,430 2,788 Change in Plan Assets Fair value of plan assets at January 1 9,948 4,766 9,550 4,174 — — Actual return on plan assets (566 ) (9 ) 1,384 319 — — Foreign currency exchange rate changes — (221 ) — 358 — — Employer contributions 803 232 728 252 166 151 Plan participants' contributions — 4 — 4 71 78 Benefits paid (1,653 ) (432 ) (1,714 ) (310 ) (237 ) (229 ) Divestitures — (198 ) — (31 ) — — Fair value of plan assets at December 31 8,532 4,142 9,948 4,766 — — Funded status at December 31 $ (3,194 ) $ (678 ) $ (3,632 ) $ (774 ) $ (2,430 ) $ (2,788 )
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, 2018 and 2017 , include: Pension Benefits 2018 2017 Other Benefits U.S. Int’l. U.S. Int’l. 2018 2017 Deferred charges and other assets $ 17 $ 412 $ 21 $ 448 $ — $ — Accrued liabilities (180 ) (66 ) (188 ) (100 ) (175 ) (174 ) Noncurrent employee benefit plans (3,031 ) (1,024 ) (3,465 ) (1,122 ) (2,255 ) (2,614 ) Net amount recognized at December 31 $ (3,194 ) $ (678 ) $ (3,632 ) $ (774 ) $ (2,430 ) $ (2,788 )
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 $4,448 and $5,286 at the end of 2018 and 2017 , respectively. These amounts consisted of: Pension Benefits 2018 2017 Other Benefits U.S. Int’l. U.S. Int’l. 2018 2017 Net actuarial loss $ 3,694 $ 955 $ 4,258 $ 1,005 $ (56 ) $ 207 Prior service (credit) costs 7 104 9 94 (256 ) (287 ) Total recognized at December 31 $ 3,701 $ 1,059 $ 4,267 $ 1,099 $ (312 ) $ (80 )
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, 2018 and 2017 , was: Pension Benefits 2018 2017 U.S. Int’l. U.S. Int’l. Projected benefit obligations $ 11,667 $ 1,277 $ 13,514 $ 1,590 Accumulated benefit obligations 10,456 1,062 12,129 1,326 Fair value of plan assets 8,456 198 9,862 413
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 2018 , 2017 and 2016 are shown in the table below: Pension Benefits 2018 2017 2016 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2018 2017 2016 Net Periodic Benefit Cost Service cost $ 480 $ 141 $ 489 $ 151 $ 494 $ 159 $ 42 $ 32 $ 60 Interest cost 370 206 366 219 377 261 94 95 128 Expected return on plan assets (636 ) (253 ) (597 ) (239 ) (723 ) (243 ) — — — Amortization of prior service costs (credits) 2 10 (5 ) 13 (9 ) 14 (28 ) (28 ) 14 Recognized actuarial losses 304 29 340 44 335 47 15 (5 ) 19 Settlement losses 411 33 436 2 511 6 — — — Curtailment losses (gains) — 3 — — — — — — — Total net periodic benefit cost 931 169 1,029 190 985 244 123 94 221 Changes Recognized in Comprehensive Income Net actuarial (gain) loss during period 151 12 381 (94 ) 690 55 (248 ) 284 (430 ) Amortization of actuarial loss (715 ) (62 ) (776 ) (46 ) (846 ) (53 ) (15 ) 5 (19 ) Prior service (credits) costs during period — 23 — 1 — — 3 — (345 ) Amortization of prior service (costs) credits (2 ) (13 ) 5 (13 ) 9 (14 ) 28 28 (14 ) Total changes recognized in other (566 ) (40 ) (390 ) (152 ) (147 ) (12 ) (232 ) 317 (808 ) Recognized in Net Periodic Benefit Cost and Other Comprehensive Income $ 365 $ 129 $ 639 $ 38 $ 838 $ 232 $ (109 ) $ 411 $ (587 )
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 2018 2017 2016 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2018 2017 2016 Assumptions used to determine benefit obligations: Discount rate 4.2 % 4.4 % 3.5 % 3.9 % 3.9 % 4.3 % 4.4 % 3.8 % 4.3 % Rate of compensation increase 4.5 % 4.0 % 4.5 % 4.0 % 4.5 % 4.5 % N/A N/A N/A Assumptions used to determine net periodic benefit cost: Discount rate for service cost 3.7 % 3.9 % 4.2 % 4.3 % 4.4 % 5.3 % 3.9 % 4.6 % 4.9 % Discount rate for interest cost 3.0 % 3.9 % 3.0 % 4.3 % 3.0 % 5.3 % 3.5 % 3.8 % 4.0 % Expected return on plan assets 6.8 % 5.5 % 6.8 % 5.5 % 7.3 % 6.3 % N/A N/A N/A Rate of compensation increase 4.5 % 4.0 % 4.5 % 4.5 % 4.5 % 4.8 % 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 $ 12 $ (10 ) Effect on postretirement benefit obligation $ 197 $ (156 )
Fair value measurements of the Company's pension plans	The fair value measurements of the company’s pension plans for 2018 and 2017 are on the following page: U.S. Int’l. Total Level 1 Level 2 Level 3 NAV Total Level 1 Level 2 Level 3 NAV At December 31, 2017 Equities U.S. 1 $ 1,331 $ 1,331 $ — $ — — $ 652 $ 651 $ 1 $ — $ — International 2,060 2,057 3 — — 691 691 — — — Collective Trusts/Mutual Funds 2 1,089 22 — — 1,067 204 19 4 — 181 Fixed Income Government 274 — 274 — — 296 77 219 — — Corporate 1,492 — 1,492 — — 593 — 563 30 — Bank Loans 117 — 106 11 — — — — — — Mortgage/Asset Backed 1 — 1 — — 8 — 8 — — Collective Trusts/Mutual Funds 2 1,130 — — — 1,130 1,481 — 16 — 1,465 Mixed Funds 3 — — — — — 80 1 79 — — Real Estate 4 1,096 — — — 1,096 376 — — 56 320 Alternative Investments 5 1,022 — — — 1,022 — — — — — Cash and Cash Equivalents 260 255 5 — — 366 362 4 — — Other 6 76 (2 ) 28 43 7 19 (2 ) 18 3 — Total at December 31, 2017 $ 9,948 $ 3,663 $ 1,909 $ 54 4,322 $ 4,766 $ 1,799 $ 912 $ 89 $ 1,966 At December 31, 2018 Equities U.S. 1 $ 1,110 $ 1,110 $ — $ — $ — $ 520 $ 520 $ — $ — $ — International 1,631 1,630 1 — — 521 520 — 1 — Collective Trusts/Mutual Funds 2 893 21 — — 872 152 9 — — 143 Fixed Income Government 225 — 225 — — 254 97 157 — — Corporate 1,382 — 1,382 — — 409 — 389 20 — Bank Loans 119 — 114 5 — — — — — — Mortgage/Asset Backed 1 — 1 — — 6 — 6 — — Collective Trusts/Mutual Funds 2 877 — — — 877 1,521 15 — — 1,506 Mixed Funds 3 — — — — — 74 3 71 — — Real Estate 4 1,065 — — — 1,065 378 — — 56 322 Alternative Investments 5 941 — — — 941 — — — — — Cash and Cash Equivalents 212 208 4 — — 287 277 2 — 8 Other 6 76 (4 ) 31 44 5 20 — 17 3 — Total at December 31, 2018 $ 8,532 $ 2,965 $ 1,758 $ 49 $ 3,760 $ 4,142 $ 1,441 $ 642 $ 80 $ 1,979 1 U.S. equities include investments in the company’s common stock in the amount of $9 at December 31, 2018 , and $12 at December 31, 2017 . 2 Collective Trusts/Mutual Funds for U.S. plans are entirely index funds; for International plans, they are mostly unit trust and index funds. 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 third-party appraisals that occur at least once a year for each property in the portfolio. 5 Alternative investments focus on market-neutral strategies that have a low expected correlation to traditional asset classes. 6 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 (Level 3); and investments in private-equity limited partnerships (NAV).
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: Equity Fixed Income International Corporate Bank Loans Real Estate Other Total Total at December 31, 2016 $ — $ 19 $ 11 $ 60 $ 44 $ 134 Actual Return on Plan Assets: Assets held at the reporting date — 1 — 1 — 2 Assets sold during the period — — — — — — Purchases, Sales and Settlements — 10 3 (5 ) 2 10 Transfers in and/or out of Level 3 — — (3 ) — — (3 ) Total at December 31, 2017 $ — $ 30 $ 11 $ 56 $ 46 $ 143 Actual Return on Plan Assets: Assets held at the reporting date 4 (2 ) — 13 — 15 Assets sold during the period (4 ) — — — — (4 ) Purchases, Sales and Settlements — (7 ) (4 ) (13 ) — (24 ) Transfers in and/or out of Level 3 1 — (2 ) — — (1 ) Total at December 31, 2018 $ 1 $ 21 $ 5 $ 56 $ 46 $ 129
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 2019 $ 1,310 $ 271 $ 175 2020 $ 1,240 $ 266 $ 172 2021 $ 1,170 $ 577 $ 171 2022 $ 1,145 $ 228 $ 168 2023 $ 1,118 $ 234 $ 166 2024-2028 $ 4,972 $ 1,392 $ 795

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2018
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 2018 , 2017 and 2016 : 2018 2017 2016 Balance at January 1 $ 14,214 $ 14,243 $ 15,642 Liabilities incurred 96 684 204 Liabilities settled (830 ) (1,721 ) (1,658 ) Accretion expense 654 668 749 Revisions in estimated cash flows (84 ) 340 (694 ) Balance at December 31 $ 14,050 $ 14,214 $ 14,243

Other Financial Information (Ta

Other Financial Information (Tables)	12 Months Ended
	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Other Financial Information	Other financial information is as follows: Year ended December 31 2018 2017 2016 Total financing interest and debt costs $ 921 $ 902 $ 753 Less: Capitalized interest 173 595 552 Interest and debt expense $ 748 $ 307 $ 201 Research and development expenses $ 453 $ 433 $ 476 Excess of replacement cost over the carrying value of inventories (LIFO method) $ 5,134 $ 3,937 $ 2,942 LIFO profits (losses) on inventory drawdowns included in earnings $ 26 $ (5 ) $ (88 ) Foreign currency effects * $ 611 $ (446 ) $ 58 * Includes $416 , $(45) and $1 in 2018 , 2017 and 2016 , respectively, for the company’s share of equity affiliates’ foreign currency effects.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Details)	12 Months Ended
	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maturity period of bank time deposits reported as time deposits, minimum	90 days
Revenue, performance obligation, description of timing	Payment is generally due within 30 days of delivery.
Performance Shares | Chevron Long-Term Incentive Plan (LTIP)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	3 years

Changes in Accumulated Other _3

Changes in Accumulated Other Comprehensive Losses - Summary of Changed (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at January 1		$ 149,319	$ 146,722	$ 153,886
Components of Other Comprehensive Income (Loss):
Before Reclassifications		4	(256)	(156)
Reclassifications		603	510	604
Other Comprehensive Gain, Net of Tax		607	254	448
Stranded Tax Reclassification to Retained Earnings	$ 562	(562)
Balance at December 31	155,642	155,642	149,319	146,722
Income tax expense (benefit)		5,715	(48)	(1,729)
Currency Translation Adjustments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at January 1		(105)	(162)	(140)
Components of Other Comprehensive Income (Loss):
Before Reclassifications		(19)	57	(22)
Reclassifications		0	0	0
Other Comprehensive Gain, Net of Tax		(19)	57	(22)
Stranded Tax Reclassification to Retained Earnings		0
Balance at December 31	(124)	(124)	(105)	(162)
Unrealized Holding Gains (Losses) on Securities
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at January 1		(5)	(2)	(29)
Components of Other Comprehensive Income (Loss):
Before Reclassifications		(5)	(3)	27
Reclassifications		0	0	0
Other Comprehensive Gain, Net of Tax		(5)	(3)	27
Stranded Tax Reclassification to Retained Earnings		0
Balance at December 31	(10)	(10)	(5)	(2)
Derivatives
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at January 1		(2)	(2)	(2)
Components of Other Comprehensive Income (Loss):
Before Reclassifications		0	0	0
Reclassifications		0	0	0
Other Comprehensive Gain, Net of Tax		0	0	0
Stranded Tax Reclassification to Retained Earnings		0
Balance at December 31	(2)	(2)	(2)	(2)
Defined Benefit Plans
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at January 1		(3,477)	(3,677)	(4,120)
Components of Other Comprehensive Income (Loss):
Before Reclassifications		28	(310)	(161)
Reclassifications		603	510	604
Other Comprehensive Gain, Net of Tax		631	200	443
Stranded Tax Reclassification to Retained Earnings		(562)
Balance at December 31	(3,408)	(3,408)	(3,477)	(3,677)
Defined Benefit Plans | Reclassification out of Accumulated Other Comprehensive Income
Components of Other Comprehensive Income (Loss):
Reclassification, before tax amount		779
Income tax expense (benefit)		176
Accumulated Other Comprehensive Loss
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at January 1		(3,589)	(3,843)	(4,291)
Components of Other Comprehensive Income (Loss):
Other Comprehensive Gain, Net of Tax		607	254	448
Balance at December 31	$ (3,544)	$ (3,544)	$ (3,589)	$ (3,843)

Information Relating to the C_3

Information Relating to the Consolidated Statement of Cash Flows - Summary of Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Net decrease (increase) in operating working capital was composed of the following:
Decrease (increase) in accounts and notes receivable		$ 437	$ (915)	$ (2,121)
Decrease (increase) in inventories		(424)	(267)	603
Decrease (increase) in prepaid expenses and other current assets		(149)	173	829
Increase (decrease) in accounts payable and accrued liabilities		(494)	998	366
Increase (decrease) in income and other taxes payable		(88)	531	(4)
Net decrease (increase) in operating working capital	[1]	(718)	520	(327)
Net cash provided by operating activities includes the following cash payments:
Interest on debt (net of capitalized interest)		736	265	158
Income taxes		4,748	3,132	1,935
Proceeds and deposits related to asset sales and returns of investment consisted of the following gross amounts:
Proceeds and deposits related to asset sales		2,000	4,930	3,154
Returns of investment from equity affiliates		392	166	322
Proceeds and deposits related to asset sales and returns of investment	[1],[2]	2,392	5,096	3,476
Net maturities (investments) of time deposits consisted of the following gross amounts:
Investments in time deposits		(950)	0	0
Time deposits matured		0	0	0
Net sales (purchases) of time deposits		(950)	0	0
Net sales (purchases) of marketable securities consisted of the following gross amounts:
Marketable securities purchased		(51)	(3)	(9)
Marketable securities sold		0	7	306
Net sales (purchases) of marketable securities		(51)	4	297
Net repayment (borrowing) of loans by equity affiliates:
Borrowing of loans by equity affiliates		0	(142)	(2,341)
Repayment of loans by equity affiliates		111	126	307
Net repayment (borrowing) of loans by equity affiliates		111	(16)	(2,034)
Net borrowings (repayments) of short-term obligations consisted of the following gross and net amounts:
Proceeds from issuances of short-term obligations		2,486	5,051	14,778
Repayments of short-term obligations		(4,136)	(8,820)	(12,558)
Net borrowings (repayments) of short-term obligations with three months or less maturity		3,671	(1,373)	(90)
Net borrowings (repayments) of short-term obligations		2,021	(5,142)	2,130
Capital expenditures
Additions to properties, plant and equipment		13,384	13,222	17,742
Additions to investments		65	25	55
Current-year dry hole expenditures		344	157	313
Payments for other liabilities and assets, net		(1)	0	(1)
Capital expenditures		13,792	13,404	18,109
Expensed exploration expenditures		523	666	544
Assets acquired through capital lease obligations and other financing obligations		75	8	5
Capital and exploratory expenditures, excluding equity affiliates		14,390	14,078	18,658
Company's share of expenditures by equity affiliates		5,716	4,743	3,770
Capital and exploratory expenditures, including equity affiliates		20,106	18,821	22,428
Non-cash additions to properties, plant and equipment		$ 25	$ 1,183	$ 56
[1]	2017 and 2016 adjusted to conform to ASU 2016-18. Refer to Note 3, "Information Relating to the Consolidated Statement of Cash Flows" beginning on page 59.
[2]	2017 and 2016 adjusted to conform to ASU 2016-15. Refer to Note 3, "Information Relating to the Consolidated Statement of Cash Flows" beginning on page 59.

Information Relating to the C_4

Information Relating to the Consolidated Statement of Cash Flows - Narrative (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Share repurchase price		$ 1,751	$ 1	$ 2
Stock repurchased during period (in shares)		14,900,000	0	0
Stock repurchased during period, value		$ 1,750	$ 0	$ 0
Amounts reclassified due to adoption of new accounting standard	[1]	(3,580)	(2,380)	(1,549)
Operating Segments | Upstream
Segment Reporting Information [Line Items]
Non cash transaction in operating segments		$ 1,100
Accounting Standards Update 2016-15
Segment Reporting Information [Line Items]
Amounts reclassified due to adoption of new accounting standard			$ 166	$ 322
[1]	2017 and 2016 adjusted to conform to ASU 2016-15. Refer to Note 3, "Information Relating to the Consolidated Statement of Cash Flows" beginning on page 59.

Information Relating to the C_5

Information Relating to the Consolidated Statement of Cash Flows - Cash Balances (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Supplemental Cash Flow Elements [Abstract]
Cash and cash equivalents	$ 9,342	$ 4,813	$ 6,988	$ 11,022
Restricted cash included in Prepaid expenses and other current assets	341	405	488	196
Restricted cash included in Deferred charges and other assets	798	725	938	904
Total cash, cash equivalents and restricted cash	$ 10,481	$ 5,943	$ 8,414	$ 12,122

New Accounting Standards (Detai

New Accounting Standards (Details) - USD ($) $ in Millions		3 Months Ended	12 Months Ended
		Dec. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 01, 2019
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating expenses	[1]		$ (20,544)	$ (19,127)	$ (19,902)
Selling, general and administrative expenses	[1]		(3,838)	(4,110)	(4,305)
Tax Cuts and Jobs Act of 2017, reclassification from AOCI to retained earnings, tax effect		$ 562	$ (562)
Accounting Standards Update 2016-02 | Scenario, Forecast
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease, right-of-use asset						$ 4,000
Operating lease, liability						$ 4,000
Accounting Standards Update 2017-07
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating expenses				310	(366)
Selling, general and administrative expenses				$ 338	$ 379
[1]	2017 and 2016 adjusted to conform to ASU 2017-07. Refer to Note 4, "New Accounting Standards" beginning on page 60.

Lease Commitments (Details)

Lease Commitments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule of capitalized leased assets
Upstream	$ 719	$ 678
Downstream	99	99
All Other	0	0
Total	818	777
Less: Accumulated amortization	617	515
Net capitalized leased assets	201	262
Rental expenses incurred for operating leases
Minimum rentals	820	726	$ 943
Contingent rentals	1	1	2
Total	821	727	945
Less: Sublease rental income	5	6	7
Net rental expense	$ 816	$ 721	$ 938
Non-cancelable term of operating and capital leases (in years)	1 year
Operating Leases
Operating Leases, 2019	$ 540
Operating Leases, 2020	492
Operating Leases, 2021	378
Operating Leases, 2022	242
Operating Leases, 2023	166
Operating Leases, Thereafter	341
Operating Leases, Total	2,159
Capital Leases
Capital Leases, 2019	30
Capital Leases, 2020	22
Capital Leases, 2021	17
Capital Leases, 2022	16
Capital Leases, 2023	16
Capital Leases, Thereafter	132
Capital Leases, Total	233
Less: Amounts representing interest and executory costs	(88)
Net present values	145
Less: Capital lease obligations included in short-term debt	(18)
Long-term capital lease obligations	127
Lessee, Capital Lease, Lease Not yet Commenced, Future Payments [Abstract]
2,019	14
2,020	15
2,021	22
2,022	21
2,023	21
Thereafter	$ 219

Summarized Financial Data - C_3

Summarized Financial Data - Chevron U.S.A. Inc. - Summary of Income Statement Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Subsidiary Statements Captions [Line Items]
Sales and other operating revenues	[1]	$ 158,902
Sales and other operating revenues	[1]		$ 134,674	$ 110,215
Total costs and other deductions		145,764	132,501	116,632
Net Income (Loss) Attributable to Chevron Corporation		14,824	9,195	(497)
Chevron U.S.A. Inc.
Subsidiary Statements Captions [Line Items]
Sales and other operating revenues		125,076
Sales and other operating revenues			104,054	83,715
Total costs and other deductions		121,351	103,904	87,429
Net Income (Loss) Attributable to Chevron Corporation		$ 4,334	$ 4,842	$ (1,177)
[1]	2017 and 2016 include excise, value-added and similar taxes of $7,189 and $6,905, respectively, collected on behalf of third parties. Beginning in 2018, these taxes are netted in "Taxes other than on income" in accordance with Accounting Standards Update (ASU) 2014-09. Refer to Note 25, "Revenue" beginning on page 88.

Summarized Financial Data - C_4

Summarized Financial Data - Chevron U.S.A. Inc. - Summary of Balance Sheet Information (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Subsidiary Statements Captions [Line Items]
Current assets	$ 34,021	$ 28,560
Current liabilities	27,171	27,737
Total CUSA net equity	155,642	149,319	$ 146,722	$ 153,886
Chevron U.S.A. Inc.
Subsidiary Statements Captions [Line Items]
Current assets	12,819	12,163
Other assets	55,814	54,994
Current liabilities	16,376	17,379
Other liabilities	12,906	12,541
Total CUSA net equity	39,351	37,237
Memo: Total debt	$ 3,049	$ 3,056

Summarized Financial Data - T_3

Summarized Financial Data - Tengizchevroil LLP - Summary of Income Statement Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Affiliate Statements Captions [Line Items]
Percentage of affiliate by summarized financial information	100.00%
Tengizchevroil LLP
Affiliate Statements Captions [Line Items]
Percentage of affiliate by summarized financial information	100.00%
Sales and other operating revenues	$ 17,260	$ 13,363	$ 10,460
Costs and other deductions	7,446	6,507	6,822
Net income attributable to affiliates	$ 6,908	$ 4,841	$ 2,563
Tengizchevroil LLP
Affiliate Statements Captions [Line Items]
Equity method investment, ownership percentage	50.00%

Summarized Financial Data - T_4

Summarized Financial Data - Tengizchevroil LLP - Summary of Balance Sheet Information (Details) - Tengizchevroil LLP - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Affiliate Statements Captions [Line Items]
Current assets	$ 2,374	$ 4,239
Other assets	34,727	26,411
Current liabilities	3,069	2,517
Other liabilities	6,357	6,266
Total affiliates' net equity	$ 27,675	$ 21,867

Fair Value Measurements - Summa

Fair Value Measurements - Summary of Assets and Liabiliites Measured on a Recurring Basis (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives	$ 283	$ 22
Derivatives	12	124
Recurring basis
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	53	9
Derivatives	283	22
Total assets at fair value	336	31
Derivatives	12	124
Total liabilities at fair value	12	124
Recurring basis | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	53	9
Derivatives	185	0
Total assets at fair value	238	9
Derivatives	0	78
Total liabilities at fair value	0	78
Recurring basis | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	0	0
Derivatives	98	22
Total assets at fair value	98	22
Derivatives	12	46
Total liabilities at fair value	12	46
Recurring basis | Level 3
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 - Sum_2

Fair Value Measurements - Summary of Assets and Liabilities Measured On a Non-Recurring Basis (Details) - Nonrecurring basis - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Properties, plant and equipment, net (held and used)	$ 102	$ 603
Properties, plant and equipment, net (held for sale)	1,694	1,378
Investments and advances	81	28
Total assets at fair value	1,877	2,009
Properties, plant and equipment, net (held and used), Before-Tax Loss	97	658
Properties, plant and equipment, net (held for sale), Before-Tax Loss	638	363
Investments and advances, Before-Tax Loss	69	26
Total nonrecurring assets at fair value, Before-Tax Loss	804	1,047
Level 1
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 assets at fair value	0	0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Properties, plant and equipment, net (held and used)	62	0
Properties, plant and equipment, net (held for sale)	1,273	1,378
Investments and advances	20	1
Total assets at fair value	1,355	1,379
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Properties, plant and equipment, net (held and used)	40	603
Properties, plant and equipment, net (held for sale)	421	0
Investments and advances	61	27
Total assets at fair value	$ 522	$ 630

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	$ 9,342,000,000	$ 4,813,000,000	$ 6,988,000,000	$ 11,022,000,000
Time deposits	950,000,000	0
Carrying/fair value of investments not included in cash and cash equivalents	1,139,000,000	1,130,000,000
Carrying amount of long-term debt	23,730,000,000	30,234,000,000
Corporate Bond Securities | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of debt	17,858,000,000
Other Long-term Debt | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of debt	871,000,000
Carrying Amount of Long-term Debt
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying amount of long-term debt	18,706,000,000	23,477,000,000
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying amount of long-term debt	$ 18,729,000,000	$ 23,943,000,000
Maximum
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 Inst_3

Financial and Derivative Instruments - Fair Value of Derivatives Not Designated as Hedging Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Derivatives, Fair Value [Line Items]
Total assets at fair value	$ 283	$ 22
Total liabilities at fair value	12	124
Commodity | Accounts and notes receivable, net
Derivatives, Fair Value [Line Items]
Total assets at fair value	279	22
Commodity | Long-term receivables, net
Derivatives, Fair Value [Line Items]
Total assets at fair value	4	0
Commodity | Accounts payable
Derivatives, Fair Value [Line Items]
Total liabilities at fair value	12	122
Commodity | Deferred credits and other noncurrent obligations
Derivatives, Fair Value [Line Items]
Total liabilities at fair value	$ 0	$ 2

Financial and Derivative Inst_4

Financial and Derivative Instruments Financial and Derivative Instruments - Effect of Derivatives Not Designated On Hedging Instruments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ 105	$ (116)	$ (300)
Commodity | Sales and other operating revenues
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	135	(105)	(269)
Commodity | Purchased crude oil and products
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	(33)	(9)	(31)
Commodity | Other income
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ 3	$ (2)	$ 0

Financial and Derivative Inst_5

Financial and Derivative Instruments Financial and Derivative Instruments - Effect of Netting Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Offsetting Assets [Abstract]
Derivative Asset, Gross Amount Recognized	$ 3,685	$ 1,169
Derivative Asset, Gross Amounts Offset	3,402	1,147
Derivative Asset, Net Amounts Presented	283	22
Derivative Asset, Gross Amounts Not Offset	0	0
Derivative Asset, Net Amount	283	22
Offsetting Liabilities [Abstract]
Derivative Liability, Gross Amount Recognized	3,414	1,271
Derivative Liability, Gross Amounts Offset	3,402	1,147
Derivative Liability, Net Amounts Presented	12	124
Derivative Liability, Gross Amounts Not Offset	0	0
Derivative Liability, Net Amount	$ 12	$ 124

Assets Held For Sale (Details)

Assets Held For Sale (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Assets held for sale	$ 1,863	$ 640
Disposal Group, Held-for-sale or Disposed of by Sales, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Assets held for sale	$ 1,863

Equity (Details)

Equity (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Company's share of undistributed earnings for equity affiliates	$ 22,362	$ 18,473
Shares remaining available for issuance (in shares)	748,211
Shares available for issuance (in shares)	1,600,000
Chevron Long-Term Incentive Plan (LTIP)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares remaining available for issuance (in shares)	78,000,000
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, 2018	Dec. 31, 2017	Dec. 31, 2016
Basic EPS Calculation
Earnings available to common stockholders - Basic	$ 14,824	$ 9,195	$ (497)
Weighted-average number of common shares outstanding (in shares)	1,897	1,882	1,872
Add: Deferred awards held as stock units (in shares)	1	1	1
Total weighted-average number of common shares outstanding (in shares)	1,898	1,883	1,873
Earnings per share of common stock - Basic (in dollars per share)	$ 7.81	$ 4.88	$ (0.27)
Diluted EPS Calculation
Earnings available to common stockholders - Diluted	$ 14,824	$ 9,195	$ (497)
Weighted-average number of common shares outstanding (in shares)	1,897	1,882	1,872
Add: Deferred awards held as stock units (in shares)	1	1	1
Add: Dilutive effect of employee stock-based awards (in shares)	16	15	0
Total weighted-average number of common shares outstanding (in shares)	1,914	1,898	1,873
Earnings per share of common stock - Diluted (in dollars per share)	$ 7.74	$ 4.85	$ (0.27)
Employee-based Awards
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of EPS (in shares)			10

Operating Segments and Geogra_3

Operating Segments and Geographic Data - Narrative (Details)	12 Months Ended
	Dec. 31, 2018segment
Segment Reporting [Abstract]
Number of reportable segments (in segments)	2
Number of operating segments (in segments)	2

Operating Segments and Geogra_4

Operating Segments and Geographic Data - Segment Earnings (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Net Income (Loss) Attributable to Chevron Corporation	$ 14,824	$ 9,195	$ (497)
Operating Segments
Segment Reporting Information [Line Items]
Net Income (Loss) Attributable to Chevron Corporation	17,114	13,364	898
Operating Segments | Upstream
Segment Reporting Information [Line Items]
Net Income (Loss) Attributable to Chevron Corporation	13,316	8,150	(2,537)
Operating Segments | Upstream | United States
Segment Reporting Information [Line Items]
Net Income (Loss) Attributable to Chevron Corporation	3,278	3,640	(2,054)
Operating Segments | Upstream | International
Segment Reporting Information [Line Items]
Net Income (Loss) Attributable to Chevron Corporation	10,038	4,510	(483)
Operating Segments | Downstream
Segment Reporting Information [Line Items]
Net Income (Loss) Attributable to Chevron Corporation	3,798	5,214	3,435
Operating Segments | Downstream | United States
Segment Reporting Information [Line Items]
Net Income (Loss) Attributable to Chevron Corporation	2,103	2,938	1,307
Operating Segments | Downstream | International
Segment Reporting Information [Line Items]
Net Income (Loss) Attributable to Chevron Corporation	1,695	2,276	2,128
Segment Reconciling Items
Segment Reporting Information [Line Items]
Interest expense	(713)	(264)	(168)
Interest income	137	60	58
Other	$ (1,714)	$ (3,965)	$ (1,285)

Operating Segments and Geogra_5

Operating Segments and Geographic Data - Segment Assets (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Total Assets	$ 253,863	$ 253,806
Goodwill	4,518	4,531
United States
Segment Reporting Information [Line Items]
Total Assets	71,560	68,910
International
Segment Reporting Information [Line Items]
Total Assets	177,785	180,365
Operating Segments
Segment Reporting Information [Line Items]
Total Assets	240,461	245,549
Operating Segments | Upstream
Segment Reporting Information [Line Items]
Total Assets	200,973	204,913
Goodwill	4,518	4,531
Operating Segments | Upstream | United States
Segment Reporting Information [Line Items]
Total Assets	42,594	40,770
Operating Segments | Upstream | International
Segment Reporting Information [Line Items]
Total Assets	153,861	159,612
Operating Segments | Downstream
Segment Reporting Information [Line Items]
Total Assets	39,488	40,636
Operating Segments | Downstream | United States
Segment Reporting Information [Line Items]
Total Assets	23,866	23,202
Operating Segments | Downstream | International
Segment Reporting Information [Line Items]
Total Assets	15,622	17,434
Segment Reconciling Items
Segment Reporting Information [Line Items]
Total Assets	13,402	8,257
Segment Reconciling Items | United States
Segment Reporting Information [Line Items]
Total Assets	5,100	4,938
Segment Reconciling Items | International
Segment Reporting Information [Line Items]
Total Assets	$ 8,302	$ 3,319

Operating Segments and Geogra_6

Operating Segments and Geographic Data - Segment Sales and Operating Revenues (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues	[1]	$ 158,902
Total Sales and Other Operating Revenues	[1]		$ 134,674	$ 110,215
Operating Segments
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		191,228
Total Sales and Other Operating Revenues			157,505	129,030
Intersegment
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		(32,326)
Total Sales and Other Operating Revenues			(22,831)	(18,815)
Total All Other
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		1,044
Total Sales and Other Operating Revenues			1,048	1,142
United States
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		1,022
Total Sales and Other Operating Revenues			1,022	1,105
United States | Operating Segments
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		83,289
Total Sales and Other Operating Revenues			67,404	56,187
United States | Intersegment
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		786
Total Sales and Other Operating Revenues			814	960
United States | All Other
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		236
Total Sales and Other Operating Revenues			208	145
International
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		22
Total Sales and Other Operating Revenues			26	37
International | Operating Segments
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		107,939
Total Sales and Other Operating Revenues			90,101	72,843
International | Intersegment
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		22
Total Sales and Other Operating Revenues			25	36
International | All Other
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		0
Total Sales and Other Operating Revenues			1	1
Upstream
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		60,713
Total Sales and Other Operating Revenues			41,922	33,145
Upstream | United States
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		22,891
Total Sales and Other Operating Revenues			13,242	10,365
Upstream | United States | Operating Segments
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		8,926
Total Sales and Other Operating Revenues			3,901	3,148
Upstream | United States | Intersegment
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		13,965
Total Sales and Other Operating Revenues			9,341	7,217
Upstream | International
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		37,822
Total Sales and Other Operating Revenues			28,680	22,780
Upstream | International | Operating Segments
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		24,143
Total Sales and Other Operating Revenues			17,209	13,262
Upstream | International | Intersegment
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		13,679
Total Sales and Other Operating Revenues			11,471	9,518
Downstream
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		129,471
Total Sales and Other Operating Revenues			114,535	94,743
Downstream | United States
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		59,376
Total Sales and Other Operating Revenues			53,140	44,717
Downstream | United States | Operating Segments
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		56,634
Total Sales and Other Operating Revenues			48,728	40,366
Downstream | United States | Intersegment
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		2,742
Total Sales and Other Operating Revenues			14	16
Downstream | United States | Excise and similar taxes
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		0
Total Sales and Other Operating Revenues			4,398	4,335
Downstream | International
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		70,095
Total Sales and Other Operating Revenues			61,395	50,026
Downstream | International | Operating Segments
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		68,963
Total Sales and Other Operating Revenues			57,438	46,388
Downstream | International | Intersegment
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		1,132
Total Sales and Other Operating Revenues			1,166	1,068
Downstream | International | Excise and similar taxes
Segment Reporting Information [Line Items]
Total Sales and Other Operating Revenues		$ 0
Total Sales and Other Operating Revenues			$ 2,791	$ 2,570
[1]	2017 and 2016 include excise, value-added and similar taxes of $7,189 and $6,905, respectively, collected on behalf of third parties. Beginning in 2018, these taxes are netted in "Taxes other than on income" in accordance with Accounting Standards Update (ASU) 2014-09. Refer to Note 25, "Revenue" beginning on page 88.

Operating Segments and Geogra_7

Operating Segments and Geographic Data - Segement Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	$ 5,715	$ (48)	$ (1,729)
Operating Segments | Upstream
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	5,498	(1,289)	(1,006)
Operating Segments | Upstream | United States
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	811	(3,538)	(1,172)
Operating Segments | Upstream | International
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	4,687	2,249	166
Operating Segments | Downstream
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	862	231	987
Operating Segments | Downstream | United States
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	534	(419)	503
Operating Segments | Downstream | International
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	328	650	484
All Other
Segment Reporting Information [Line Items]
Total Income Tax Expense (Benefit)	$ (645)	$ 1,010	$ (1,710)

Investments and Advances - Summ

Investments and Advances - Summary of Investment and Advances and Equity in Earnings (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Investments and Advances	$ 35,261	$ 32,105
Other non-equity method investments	285	392
Total investments and advances	35,546	32,497
Equity in Earnings	6,327	4,438	$ 2,661
United States | Investments and Advances
Schedule of Equity Method Investments [Line Items]
Total investments and advances	7,500	7,582
United States | Equity in Earnings
Schedule of Equity Method Investments [Line Items]
Equity in Earnings	1,033	788	802
International | Investments and Advances
Schedule of Equity Method Investments [Line Items]
Total investments and advances	28,046	24,915
International | Equity in Earnings
Schedule of Equity Method Investments [Line Items]
Equity in Earnings	5,294	3,650	1,859
All Other
Schedule of Equity Method Investments [Line Items]
Investments and Advances	(16)	(15)
Equity in Earnings	(2)	(1)	(4)
Upstream | Operating Segments
Schedule of Equity Method Investments [Line Items]
Investments and Advances	23,752	20,843
Equity in Earnings	4,649	3,196	1,243
Upstream | Operating Segments | Tengizchevroil
Schedule of Equity Method Investments [Line Items]
Investments and Advances	16,017	13,121
Equity in Earnings	3,614	2,581	1,380
Upstream | Operating Segments | Petropiar
Schedule of Equity Method Investments [Line Items]
Investments and Advances	1,361	1,152
Equity in Earnings	317	175	326
Upstream | Operating Segments | Petroboscan
Schedule of Equity Method Investments [Line Items]
Investments and Advances	1,315	1,080
Equity in Earnings	357	154	(133)
Upstream | Operating Segments | Caspian Pipeline Consortium
Schedule of Equity Method Investments [Line Items]
Investments and Advances	1,022	1,151
Equity in Earnings	170	155	145
Upstream | Operating Segments | Angola LNG Limited
Schedule of Equity Method Investments [Line Items]
Investments and Advances	2,496	2,625
Equity in Earnings	172	27	(282)
Upstream | Operating Segments | Other
Schedule of Equity Method Investments [Line Items]
Investments and Advances	1,541	1,714
Equity in Earnings	19	104	(193)
Downstream | Operating Segments
Schedule of Equity Method Investments [Line Items]
Investments and Advances	11,525	11,277
Equity in Earnings	1,680	1,243	1,422
Downstream | Operating Segments | Chevron Phillips Chemical Company LLC
Schedule of Equity Method Investments [Line Items]
Investments and Advances	6,218	6,200
Equity in Earnings	1,034	723	840
Downstream | Operating Segments | GS Caltex Corporation
Schedule of Equity Method Investments [Line Items]
Investments and Advances	3,924	3,826
Equity in Earnings	373	290	373
Downstream | Operating Segments | Other
Schedule of Equity Method Investments [Line Items]
Investments and Advances	1,383	1,251
Equity in Earnings	$ 273	$ 230	$ 209

Investments and Advances - Narr

Investments and Advances - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Variable Interest Entity [Line Items]
Percentage of affiliate by summarized financial information	100.00%
Carrying amount of long-term debt	$ 23,730	$ 30,234
Investments and advances	35,261	32,105
Related Party Transaction, Other Revenues from Transactions with Related Party	10,378	8,165	$ 5,786
Purchased crude oil and products	94,578	75,765	59,321
Accounts and notes receivable due from affiliated companies	884	1,141
Accounts payable due to affiliated companies	631	498
Chevron's loan to affiliates	3,402	3,853	3,535
Affiliated Entity | Oil and Gas, Purchased
Variable Interest Entity [Line Items]
Purchased crude oil and products	$ 6,598	$ 4,800	$ 3,468
Tengizchevroil LLP
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage	50.00%
Chevron investment carrying value over underlying equity in TCO's net assets	$ 120
Notes receivable from affiliate	$ 2,060
Petropiar
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage	30.00%
Chevron investment carrying value less underlying equity in Petropiar net assets	$ 136
Petroboscan
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage	39.20%
Chevron investment carrying value over underlying equity in Petroboscan's net assets	$ 97
Carrying amount of long-term debt	$ 626
Caspian Pipeline Consortium
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage	15.00%
Long term loans of Caspian Pipeline Consortium included in investments and advances	$ 468
Percentage of Caspian Pipeline Consortium pipeline construction funded by Loans	30.00%
Angola LNG Limited
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage	36.40%
Chevron Phillips Chemical Company LLC
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage	50.00%
GS Caltex Corporation
Variable Interest Entity [Line Items]
Equity method investment, ownership percentage	50.00%

Investments and Advances - Su_2

Investments and Advances - Summary of Financial Information of All Equity Affiliates (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Chevron
Schedule of Investments [Line Items]
Total revenues	$ 40,679	$ 33,460	$ 27,787
Income before income tax expense	6,755	5,712	3,670
Net income attributable to affiliates	6,384	4,468	2,876
Current assets	12,813	13,568	13,743
Noncurrent assets	36,369	32,643	28,854
Current liabilities	9,843	10,201	8,996
Noncurrent liabilities	4,446	4,224	4,255
Total affiliates' net equity	34,893	31,786	29,346
Affiliates
Schedule of Investments [Line Items]
Total revenues	84,469	70,744	59,253
Income before income tax expense	16,693	13,487	6,587
Net income attributable to affiliates	13,321	10,751	5,127
Current assets	32,657	33,883	33,406
Noncurrent assets	87,614	82,261	75,258
Current liabilities	26,006	26,873	24,793
Noncurrent liabilities	20,000	21,447	22,671
Total affiliates' net equity	$ 74,265	$ 67,824	$ 61,200

Litigation (Details)

Litigation (Details) - Pending Litigation $ in Millions	Nov. 13, 2013USD ($)	Aug. 03, 2012USD ($)	Feb. 14, 2011USD ($)	Dec. 31, 1991USD ($)	Dec. 31, 2018LegalMatter	Jan. 03, 2012
MTBE
Loss Contingencies [Line Items]
Pending lawsuits and claims (in number of claims) | LegalMatter					7
Ecuador Litigation
Loss Contingencies [Line Items]
Pending lawsuits and claims (in number of claims) | LegalMatter					1
Remediation program term (in years)				3 years
Remediation program				$ 40
Damages awarded	$ 9,500		$ 8,600
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%
Amount awarded to other party		$ 19,100

Taxes - Summary of Components o

Taxes - Summary of Components of Income Tax (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
U.S. federal
Current	$ (181)	$ (382)	$ (623)
Deferred	738	(2,561)	(1,558)
State and local
Current	183	(97)	(15)
Deferred	(16)	66	(121)
Total United States	724	(2,974)	(2,317)
International
Current	4,662	3,634	2,744
Deferred	329	(708)	(2,156)
Total International	4,991	2,926	588
Total income tax expense (benefit)	$ 5,715	$ (48)	$ (1,729)

Taxes - Effective Income Tax Re

Taxes - Effective Income Tax Reconcilliation and Summary of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income (loss) before income taxes
United States	$ 4,730	$ (441)	$ (4,317)
International	15,845	9,662	2,157
Income (Loss) Before Income Tax Expense	20,575	9,221	(2,160)
Effective Income Tax Rate Reconciliation, Amount [Abstract]
Theoretical tax (at U.S. statutory rate of 21% - 2018, 35% - 2017 & 2016)	4,321	3,227	(756)
Effect of U.S. tax reform	(26)	(2,020)	0
Equity affiliate accounting effect	(1,526)	(1,373)	(704)
Effect of income taxes from international operations	3,132	(130)	608
State and local taxes on income, net of U.S. federal income tax benefit	162	39	(44)
Prior year tax adjustments, claims and settlements	(51)	(39)	(349)
Tax credits	(163)	(199)	(188)
Other U.S.	(134)	447	(296)
Total income tax expense (benefit)	$ 5,715	$ (48)	$ (1,729)
Effective income tax rate	27.80%	(0.50%)	80.00%
Deferred tax liabilities
Properties, plant and equipment	$ 20,159	$ 19,869
Investments and other	4,943	4,796
Total deferred tax liabilities	25,102	24,665
Deferred tax assets
Foreign tax credits	(10,536)	(11,872)
Asset retirement obligations/environmental reserves	(5,328)	(5,511)
Employee benefits	(2,787)	(3,129)
Deferred credits	(1,373)	(1,769)
Tax loss carryforwards	(4,948)	(5,463)
Other accrued liabilities	(595)	(842)
Inventory	(505)	(336)
Miscellaneous	(3,481)	(2,415)
Total deferred tax assets	(29,553)	(31,337)
Deferred tax assets valuation allowance	15,973	16,574
Total deferred taxes, net	11,522	9,902
Classification of deferred taxes
Deferred charges and other assets	(4,399)	(4,750)
Noncurrent deferred income taxes	15,921	14,652
Total deferred taxes, net	$ 11,522	$ 9,902

Taxes - Narrative (Details)

Taxes - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Valuation Allowance [Line Items]
Increase in income tax expense	$ 5,763
Income tax expense (benefit)	$ 5,715	$ (48)	$ (1,729)
Effect of change in U.S. tax rate		$ 2,020
Effective tax rate	27.80%	(0.50%)	80.00%
Loss carry forward	$ 13,731
Tax credit carryforward	1,198
Carry forward amount of foreign tax credit with expiration dates	10,536	$ 11,872
Tax Cuts and Jobs Act of 2017, existing undistributed accumulated earnings of foreign subsidiary	$ 59,900
Percentage of impact of unrecognized tax benefits on effective tax rate if subsequently recognized	82.00%
Unrecognized tax benefits	$ 5,070	4,828	$ 3,031	$ 3,042
Income tax accruals for anticipated interest and penalty obligations	33	178
Income tax benefit expense associated with interest and penalties	8	$ (161)	$ 38
Property, Plant and Equipment
Valuation Allowance [Line Items]
Decrease in deferred tax liabilities	400
Foreign Tax Credits and Tax Loss Carry Forwards
Valuation Allowance [Line Items]
Decrease in deferred tax assets	$ 1,800

Taxes - Sumamry of Unrecognized

Taxes - Sumamry of Unrecognized Income Tax Benefits and Taxes Other Than on Income (Details 2) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Changes to company's unrecognized tax benefits
Balance at January 1		$ 4,828	$ 3,031	$ 3,042
Foreign currency effects		(6)
Foreign currency effects			43	1
Additions based on tax positions taken in current year		239	1,853	245
Additions for tax positions taken in prior years		153	1,166	181
Reductions for tax positions taken in prior years		(131)	(90)	(390)
Settlements with taxing authorities in current year		(13)	(1,173)	(36)
Reductions as a result of a lapse of the applicable statute of limitations		0	(2)	(12)
Balance at December 31		5,070	4,828	3,031
Income Tax Authority [Line Items]
Excise and similar taxes on products and merchandise			7,189	6,905
Import duties and other levies	[1]	4,867	12,331	11,668
Total taxes other than on income		4,867	12,331	11,668
United States
Income Tax Authority [Line Items]
Excise and similar taxes on products and merchandise		4,830	4,398	4,335
Consumer excise taxes collected on behalf of third parties		(4,830)	0	0
Import duties and other levies		15	11	9
Property and other miscellaneous taxes		1,577	1,824	1,680
Payroll taxes		246	241	252
Taxes on production		325	206	159
Total taxes other than on income		2,163	6,680	6,435
International
Income Tax Authority [Line Items]
Excise and similar taxes on products and merchandise		3,031	2,791	2,570
Consumer excise taxes collected on behalf of third parties		(3,031)	0	0
Import duties and other levies		37	45	33
Property and other miscellaneous taxes		2,370	2,563	2,379
Payroll taxes		132	137	145
Taxes on production		165	115	106
Total taxes other than on income		$ 2,704	$ 5,651	$ 5,233
[1]	2017 and 2016 include excise, value-added and similar taxes of $7,189 and $6,905, respectively, collected on behalf of third parties. Beginning in 2018, these taxes are netted in "Taxes other than on income" in accordance with Accounting Standards Update (ASU) 2014-09. Refer to Note 25, "Revenue" beginning on page 88.

Properties, Plant and Equipme_3

Properties, Plant and Equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Properties, Plant and Equipment
Gross Investment at Cost	$ 340,244	$ 344,485	$ 336,077
Net Investment	169,207	177,712	182,186
Additions at Cost	13,066	14,364	17,623
Depreciation Expense	19,419	19,349	19,457
Dry hole expense related to prior years expenditures, net	343	42	175
Accretion expense	654	668	749
Impairment charges	735	1,021	3,186
United States
Properties, Plant and Equipment
Gross Investment at Cost	117,507	112,998	111,987
Net Investment	52,550	51,409	52,541
Additions at Cost	7,917	6,120	5,158
Depreciation Expense	6,399	6,957	7,860
International
Properties, Plant and Equipment
Gross Investment at Cost	222,737	231,487	224,090
Net Investment	116,657	126,303	129,645
Additions at Cost	5,149	8,244	12,465
Depreciation Expense	13,020	12,392	11,597
Australia
Properties, Plant and Equipment
Net Investment	53,768	55,514	53,962
Upstream
Properties, Plant and Equipment
Gross Investment at Cost	303,484	308,813	298,486
Net Investment	153,129	161,913	165,212
Additions at Cost	11,299	12,929	16,516
Depreciation Expense	18,054	17,623	17,823
Upstream | United States
Properties, Plant and Equipment
Gross Investment at Cost	88,155	84,602	83,929
Net Investment	39,526	38,722	39,710
Additions at Cost	6,434	4,995	4,432
Depreciation Expense	5,328	5,527	6,576
Upstream | International
Properties, Plant and Equipment
Gross Investment at Cost	215,329	224,211	214,557
Net Investment	113,603	123,191	125,502
Additions at Cost	4,865	7,934	12,084
Depreciation Expense	12,726	12,096	11,247
Downstream
Properties, Plant and Equipment
Gross Investment at Cost	31,922	30,692	32,145
Net Investment	13,861	13,420	14,290
Additions at Cost	1,537	1,213	903
Depreciation Expense	1,033	1,035	1,288
Downstream | United States
Properties, Plant and Equipment
Gross Investment at Cost	24,685	23,598	22,795
Net Investment	10,838	10,346	10,196
Additions at Cost	1,259	907	528
Depreciation Expense	751	753	956
Downstream | International
Properties, Plant and Equipment
Gross Investment at Cost	7,237	7,094	9,350
Net Investment	3,023	3,074	4,094
Additions at Cost	278	306	375
Depreciation Expense	282	282	332
All Other
Properties, Plant and Equipment
Gross Investment at Cost	4,838	4,980	5,446
Net Investment	2,217	2,379	2,684
Additions at Cost	230	222	204
Depreciation Expense	332	691	346
All Other | United States
Properties, Plant and Equipment
Gross Investment at Cost	4,667	4,798	5,263
Net Investment	2,186	2,341	2,635
Additions at Cost	224	218	198
Depreciation Expense	320	677	328
All Other | International
Properties, Plant and Equipment
Gross Investment at Cost	171	182	183
Net Investment	31	38	49
Additions at Cost	6	4	6
Depreciation Expense	$ 12	$ 14	$ 18

Short-Term Debt - Sumamry (Deta

Short-Term Debt - Sumamry (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Short term borrowings
Commercial paper	$ 7,503	$ 5,379
Notes payable to banks and others with originating terms of one year or less	28	0
Current maturities of long-term debt	4,999	6,720
Current maturities of long-term capital leases	18	15
Redeemable long term obligations - Long-term debt	3,078	3,078
Redeemable long term obligations - Capital leases	0	0
Subtotal	15,626	15,192
Reclassified to long-term debt	(9,900)	(10,000)
Total short-term debt	$ 5,726	$ 5,192
Weighted-average interest rate	2.43%	1.30%
Unamortized discounts and debt issuance costs	$ 1	$ 2

Short-Term Debt - Narrative (De

Short-Term Debt - Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Committed credit facilities	$ 9,900,000,000
Debt instrument, term	364 days
Reclassified to long-term debt	$ 9,900,000,000	$ 10,000,000,000
Outstanding amount	0
Expiring in December 2017
Debt Instrument [Line Items]
Committed credit facilities	9,575,000,000
Expiring in December 2020
Debt Instrument [Line Items]
Committed credit facilities	$ 325,000,000
Debt instrument, term	5 years

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Long-term debt instruments		$ 23,730	$ 30,234
Debt due within one year		(5,000)	(6,722)
Reclassified from short-term debt		9,900	10,000
Unamortized discounts and debt issuance costs		(24)	(35)
Capital lease obligations		127	94
Total long-term debt	[1]	28,733	33,571
Long-term debt maturing 2019		5,000
Long-term debt maturing 2020		5,054
Long-term debt maturing 2021		2,272
Long-term debt maturing 2022		4,050
Long-term debt maturing 2023		3,003
Long-term debt maturing after 2023		4,351
Notes | 3.191% notes due 2023
Debt Instrument [Line Items]
Long-term debt instruments		$ 2,250	2,250
Interest rate		3.191%
Notes | 2.954% notes due 2026
Debt Instrument [Line Items]
Long-term debt instruments		$ 2,250	2,250
Interest rate		2.954%
Notes | 2.355% notes due 2022
Debt Instrument [Line Items]
Long-term debt instruments		$ 2,000	2,000
Interest rate		2.355%
Notes | 1.961% notes due 2020
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,750	1,750
Interest rate		1.961%
Notes | 4.950% notes due 2019
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,500	1,500
Interest rate		4.95%
Notes | 1.561% notes due 2019
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,350	1,350
Interest rate		1.561%
Notes | 2.100% notes due 2021
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,350	1,350
Interest rate		2.10%
Notes | 2.419% notes due 2020
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,250	1,250
Interest rate		2.419%
Notes | 2.427% notes due 2020
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,000	1,000
Interest rate		2.427%
Notes | 2.895% notes due 2024
Debt Instrument [Line Items]
Long-term debt instruments		$ 1,000	1,000
Interest rate		2.895%
Notes | 2.193% notes due 2019
Debt Instrument [Line Items]
Long-term debt instruments		$ 750	750
Interest rate		2.193%
Notes | 2.566% notes due 2023
Debt Instrument [Line Items]
Long-term debt instruments		$ 750	750
Interest rate		2.566%
Notes | 3.326% notes due 2025
Debt Instrument [Line Items]
Long-term debt instruments		$ 750	750
Interest rate		3.326%
Notes | 2.498% notes due 2022
Debt Instrument [Line Items]
Long-term debt instruments		$ 700	700
Interest rate		2.498%
Notes | 2.411% notes due 2022
Debt Instrument [Line Items]
Long-term debt instruments		$ 700	700
Interest rate		2.411%
Notes | 1.991% notes due 2020
Debt Instrument [Line Items]
Long-term debt instruments		$ 600	600
Interest rate		1.991%
Notes | 1.686% notes due 2019
Debt Instrument [Line Items]
Long-term debt instruments		$ 550	550
Interest rate		1.686%
Notes | 1.718% notes due 2018
Debt Instrument [Line Items]
Long-term debt instruments		$ 0	2,000
Interest rate		1.718%
Notes | 1.365% notes due 2018
Debt Instrument [Line Items]
Long-term debt instruments		$ 0	1,750
Interest rate		1.365%
Notes | 1.790% notes due 2018
Debt Instrument [Line Items]
Long-term debt instruments		$ 0	1,250
Interest rate		1.79%
Floating Rate Notes | Floating rate notes due 2019 (2.905%)
Debt Instrument [Line Items]
Long-term debt instruments		$ 850	850
Interest rate		2.905%
Floating Rate Notes | Floating rate notes due 2021 (3.313%)
Debt Instrument [Line Items]
Long-term debt instruments		$ 650	650
Interest rate		3.313%
Floating Rate Notes | Floating rate notes due 2022 (3.245%)
Debt Instrument [Line Items]
Long-term debt instruments		$ 650	650
Interest rate		3.254%
Floating Rate Notes | Floating rate notes due 2020 (2.948%)
Debt Instrument [Line Items]
Long-term debt instruments		$ 400	400
Interest rate		2.948%
Floating Rate Notes | Floating rate notes due 2018
Debt Instrument [Line Items]
Long-term debt instruments		$ 0	1,650
Loans | 3.400% loan
Debt Instrument [Line Items]
Long-term debt instruments		$ 218	0
Interest rate		3.40%
Loans | Amortizing bank loan due 2018
Debt Instrument [Line Items]
Long-term debt instruments		$ 0	72
Debentures | 8.625% debentures due 2032
Debt Instrument [Line Items]
Long-term debt instruments		$ 147	147
Interest rate		8.625%
Debentures | 8.625% debentures due 2031
Debt Instrument [Line Items]
Long-term debt instruments		$ 108	108
Interest rate		8.625%
Debentures | 8.000% debentures due 2032
Debt Instrument [Line Items]
Long-term debt instruments		$ 75	75
Interest rate		8.00%
Debentures | 9.750% debentures due 2020
Debt Instrument [Line Items]
Long-term debt instruments		$ 54	54
Interest rate		9.75%
Debentures | 8.875% debentures due 2021
Debt Instrument [Line Items]
Long-term debt instruments		$ 40	40
Interest rate		8.875%
Medium-term Notes | Medium-term notes, maturing from 2021 to 2038 (6.629%)
Debt Instrument [Line Items]
Long-term debt instruments		$ 38	$ 38
Interest rate		6.629%
[1]	Includes capital lease obligations of $127 and $94 at December 31, 2018 and 2017, respectively.

Accounting for Suspended Expl_3

Accounting for Suspended Exploratory Wells - Summary of Changes and Aging of Capitalized Well Costs (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2018USD ($)Project	Dec. 31, 2017USD ($)Project	Dec. 31, 2016USD ($)Project
Changes in company's suspended exploratory well costs
Beginning balance at January 1	$ 3,702	$ 3,540	$ 3,312
Additions to capitalized exploratory well costs pending the determination of proved reserves	207	323	465
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	(13)	(113)	(119)
Capitalized exploratory well costs charged to expense	(333)	(39)	(118)
Other reductions	0	(9)	0
Ending balance at December 31	3,563	3,702	3,540
Aging of capitalized well costs and number of project
Exploratory well costs capitalized for a period of one year or less				$ 202	$ 307	$ 445
Exploratory well costs capitalized for a period greater than one year				3,361	3,395	3,095
Balance at December 31	$ 3,702	$ 3,540	$ 3,312	$ 3,563	$ 3,702	$ 3,540
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project				30	32	35

Accounting for Suspended Expl_4

Accounting for Suspended Exploratory Wells - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)WellProject	Dec. 31, 2017USD ($)Project	Dec. 31, 2016USD ($)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 | $	$ 3,361	$ 3,395	$ 3,095
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project	30	32	35
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	153
Drilling Activity
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 | $	$ 1,585
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project	14
No Drilling Activity
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 | $	$ 1,776
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project	16
Undergoing Front End Engineering and Design with Final Investment Decision Expected
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 | $	$ 672
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project	3
Undergoing front-end engineering and design with final investment decision expected in three years	4 years
Development Concept Under Review by Government
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 | $	$ 93
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project	1
Reviewing Development Alternatives
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 | $	$ 963
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project	8
Miscellaneous Activities for Projects with Smaller Amounts Suspended
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 | $	$ 48
Number of projects with exploratory well costs that have been capitalized for a period greater than one year (in projects) | Project	4

Accounting for Suspended Expl_5

Accounting for Suspended Exploratory Wells - Aging of Costs on a Well and Project Basis (Details) $ in Millions	Dec. 31, 2018USD ($)WellProject	Dec. 31, 2017USD ($)Project	Dec. 31, 2016USD ($)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	$ 3,361	$ 3,395	$ 3,095
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well	153
Number of projects (in projects) | Project	30	32	35
1998-2007
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	$ 410
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well	31
2008-2012
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	$ 1,076
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well	61
2013-2017
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	$ 1,875
Capitalized exploratory well costs that have been capitalized for period greater than one year, number of wells | Well	61
2003-2010
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	$ 338
Number of projects (in projects) | Project	5
2011-2014
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	$ 894
Number of projects (in projects) | Project	10
2015-2018
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	$ 2,129
Number of projects (in projects) | Project	15

Stock Options and Other Share_3

Stock Options and Other Share-Based Compensation - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense for stock options	$ 105	$ 137	$ 271
After tax compensation expense for stock options	83	89	176
Compensation expense for stock appreciation rights restricted stock performance units and restricted stock units	60	231	371
Compensation expense for stock appreciation rights, restricted stock, performance units and restricted stock units, after tax	47	150	241
Cash received in payment for option exercises	1,159	1,100	647
Tax benefits realized for the tax deductions from option exercises	43	48	21
Cash paid to settle performance units and stock appreciation rights	$ 157	187	82
Maximum number of share that may be issued under LTIP (in shares)	748,211
Total intrinsic value options exercised	$ 506	$ 407	$ 240
Total before-tax compensation cost related to nonvested share-based compensation arrangements	$ 53
Weighted-average period of recognition of unrecognized compensation cost related to nonvested share-based compensation arrangements	1 year 7 months 6 days
Chevron Long-Term Incentive Plan (LTIP)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum number of share that may be issued under LTIP (in shares)	78,000,000
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) | Maximum | From April 2004 through May 2023
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) | Chevron Long-Term Incentive Plan (LTIP)
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) | Chevron Long-Term Incentive Plan (LTIP), 2017 Issuance
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award contractual term (in years)	3 years
Stock Options and Stock Appreciation Rights | Chevron Long-Term Incentive Plan (LTIP)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award contractual term (in years)	10 years
Stock Options and Stock Appreciation Rights | Chevron Long-Term Incentive Plan (LTIP), 2017 Issuance
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award contractual term (in years)	10 years
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares outstanding (in shares)	1,737,479	1,236,500
Shares granted (in shares)	819,769
Shares vested (in shares)	222,946
Shares forfeited (in shares)	95,844
Shares vested, fair value	$ 125
Restricted Stock Units (RSUs) | Chevron Long-Term Incentive Plan (LTIP), 2017 Issuance
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award contractual term (in years)	5 years
Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares outstanding (in shares)	3,669,730	3,090,793
Shares granted (in shares)	1,491,141
Shares vested (in shares)	746,450
Shares forfeited (in shares)	165,754
Shares vested, fair value	$ 258
Stock Appreciation Rights (SARs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares outstanding (in shares)	4,200,000
Shares vested, fair value	$ 70

Stock Options and Other Share_4

Stock Options and Other Share-Based Compensation - Summary of Valuation Assumptions and Activity (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Stock Option
Expected term in years	6 years 6 months	6 years 3 months 18 days	6 years 3 months 18 days
Volatility	21.20%	21.70%	21.70%
Risk-free interest rate based on zero coupon U.S. treasury note	2.60%	2.20%	1.60%
Dividend yield	3.80%	4.20%	4.50%
Weighted-average fair value per option granted (in dollars per share)	$ 18.18	$ 15.31	$ 9.53
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Outstanding, beginning balance (in shares)	103,765
Shares, Granted (in shares)	4,665
Shares, Exercised (in shares)	(12,991)
Shares, Forfeited (in shares)	(715)
Outstanding, ending balance (in shares)	94,724	103,765
Shares, Exercisable at December 31, 2015 (in shares)	81,074
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)	$ 97.40
Weighted-Average Exercise Price, Granted (in dollars per share)	125.35
Weighted-Average Exercise Price, Exercised (in dollars per share)	88.11
Weighted-Average Exercise Price, Forfeited (in dollars per share)	115.25
Weighted-Average Exercise Price, Outstanding at December 31, 2016 (in dollars per share)	99.92	$ 97.40
Weighted-Average Exercise Price, Exercisable at December 31, 2016 (in dollars per share)	$ 99.34
Average Remaining Contractual Term, Outstanding at December 31, 2016 (in years)	5 years 26 days
Average Remaining Contractual Term, Exercisable at December 31, 2016 (in years)	4 years 7 months 6 days
Aggregate Intrinsic Value, Outstanding at December 31, 2016	$ 1,101
Aggregate Intrinsic Value, Exercisable at December 31, 2016	$ 933

Employee Benefit Plans - Narrat

Employee Benefit Plans - Narrative (Details) - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
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	$ 4,448	$ 5,286
Net Actuarial Loss:
The percentage of the higher of the projected benefit obligation or market-related value of plan assets in excess of which net actuarial losses are amortized	10.00%
Other Benefit Assumptions:
Assumed health care cost-trend rates in the next fiscal year	7.20%	7.40%
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
Primary Investment:
Company's US and UK pension plans as a percentage of total pension assets	91.00%
Benefit Plan Trusts:
Number of Chevron treasury stocks held in benefit plan trust for funding obligations	14,168
Various grantor trust assets invested primarily in interest earning accounts	$ 34	$ 35
Employee Incentive Plan
Charges to expense for cash bonuses	1,048	936	$ 662
Other Benefits
Funded Status:
Amounts recognized on a before-tax bases in "Accumulated other comprehensive loss" for the company's pension and other postretirement benefit plans	$ (312)	$ (80)
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	13 years
Actuarial gain (loss) that will be amortized from Accumulated other comprehensive loss	$ (3)
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	8 years
Amortization of prior service (credits) costs during the next year	$ (28)
Discount Rate:
Discount rate for pension plans	4.40%	3.80%	4.30%
Cash Contributions and Benefit Payments:
Contributions to employee pension plans	$ 166	$ 151
Estimated contributions to employee pension plans for the next fiscal year	175
ESIP
Employee Savings Investment Plan:
Compensation expense	$ 270	$ 316	$ 281
U.S.
Expected Return on Plan Assets:
Estimated long-term rate of return on US pension plan assets	6.75%	6.75%	7.25%
Cash Contributions and Benefit Payments:
Contributions to employee pension plans	$ 803
Estimated contributions to employee pension plans for the next fiscal year	700
U.S. | Pension Benefits
Funded Status:
Amounts recognized on a before-tax bases in "Accumulated other comprehensive loss" for the company's pension and other postretirement benefit plans	3,701	$ 4,267
Accumulated benefit obligations pension plans	$ 10,514	$ 12,194
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	$ 239
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	$ 290
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	$ 2
Expected Return on Plan Assets:
Estimated long-term rate of return on US pension plan assets			7.50%
Percentage of US pension plan assets relative to total pension plan assets	67.00%
Plan asset market valuation period, prior to year-end measurement date	3 months
Discount Rate:
Discount rate for pension plans	4.20%	3.50%	3.90%
Cash Contributions and Benefit Payments:
Contributions to employee pension plans	$ 803	$ 728
U.S. | Pension Benefits | Equities | Minimum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	30.00%
U.S. | Pension Benefits | Equities | Maximum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	60.00%
U.S. | Pension Benefits | Fixed Income and Cash | Minimum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	20.00%
U.S. | Pension Benefits | Fixed Income and Cash | Maximum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	65.00%
U.S. | Pension Benefits | Real Estate | Minimum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	0.00%
U.S. | Pension Benefits | Real Estate | Maximum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	15.00%
U.S. | Pension Benefits | Other | Minimum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	0.00%
U.S. | Pension Benefits | Other | Maximum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	15.00%
U.S. | Other Benefits
Discount Rate:
Discount rate for pension plans	4.30%	3.60%	4.10%
Int’l.
Expected Return on Plan Assets:
Estimated long-term rate of return on US pension plan assets	5.50%	5.50%	6.30%
Cash Contributions and Benefit Payments:
Contributions to employee pension plans	$ 232
Estimated contributions to employee pension plans for the next fiscal year	200
Int’l. | Pension Benefits
Funded Status:
Amounts recognized on a before-tax bases in "Accumulated other comprehensive loss" for the company's pension and other postretirement benefit plans	1,059	$ 1,099
Accumulated benefit obligations pension plans	$ 4,360	$ 5,009
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	$ 19
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	8 years
Amortization of prior service (credits) costs during the next year	$ 12
Discount Rate:
Discount rate for pension plans	4.40%	3.90%	4.30%
Cash Contributions and Benefit Payments:
Contributions to employee pension plans	$ 232	$ 252
UNITED KINGDOM | Pension Benefits | Equities | Minimum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	25.00%
UNITED KINGDOM | Pension Benefits | Equities | Maximum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	45.00%
UNITED KINGDOM | Pension Benefits | Fixed Income and Cash | Minimum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	40.00%
UNITED KINGDOM | Pension Benefits | Fixed Income and Cash | Maximum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	75.00%
UNITED KINGDOM | Pension Benefits | Real Estate | Minimum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	5.00%
UNITED KINGDOM | Pension Benefits | Real Estate | Maximum
Primary Investment:
Pension Plan - Board of Trustees approved asset allocation	15.00%

Employee Benefit Plans - Summar

Employee Benefit Plans - Summary of Change in Benefit Obligation and Plan Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
U.S.
Change in Plan Assets
Fair value of plan assets at January 1	$ 9,948
Employer contributions	803
Fair value of plan assets at December 31	8,532	$ 9,948
Int’l.
Change in Plan Assets
Fair value of plan assets at January 1	4,766
Employer contributions	232
Fair value of plan assets at December 31	4,142	4,766
Pension Benefits | U.S.
Change in Benefit Obligation
Benefit obligation at January 1	13,580	13,271
Service cost	480	489	$ 494
Interest cost	370	366	377
Plan participants' contributions	0	0
Plan amendments	0	0
Actuarial (gain) loss	(1,051)	1,168
Foreign currency exchange rate changes	0	0
Benefits paid	(1,653)	(1,714)
Divestitures	0	0
Benefit obligation at December 31	11,726	13,580	13,271
Change in Plan Assets
Fair value of plan assets at January 1	9,948	9,550
Actual return on plan assets	(566)	1,384
Foreign currency exchange rate changes	0	0
Employer contributions	803	728
Plan participants' contributions	0	0
Benefits paid	(1,653)	(1,714)
Divestitures	0	0
Fair value of plan assets at December 31	8,532	9,948	9,550
Funded status at December 31	(3,194)	(3,632)
Pension Benefits | Int’l.
Change in Benefit Obligation
Benefit obligation at January 1	5,540	5,169
Service cost	141	151	159
Interest cost	206	219	261
Plan participants' contributions	4	4
Plan amendments	23	1
Actuarial (gain) loss	(239)	(37)
Foreign currency exchange rate changes	(227)	374
Benefits paid	(432)	(310)
Divestitures	(196)	(31)
Benefit obligation at December 31	4,820	5,540	5,169
Change in Plan Assets
Fair value of plan assets at January 1	4,766	4,174
Actual return on plan assets	(9)	319
Foreign currency exchange rate changes	(221)	358
Employer contributions	232	252
Plan participants' contributions	4	4
Benefits paid	(432)	(310)
Divestitures	(198)	(31)
Fair value of plan assets at December 31	4,142	4,766	4,174
Funded status at December 31	(678)	(774)
Other Benefits
Change in Benefit Obligation
Benefit obligation at January 1	2,788	2,549
Service cost	42	32	60
Interest cost	94	95	128
Plan participants' contributions	71	78
Plan amendments	2	0
Actuarial (gain) loss	(272)	266
Foreign currency exchange rate changes	(9)	10
Benefits paid	(237)	(229)
Divestitures	(49)	(13)
Benefit obligation at December 31	2,430	2,788	2,549
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	166	151
Plan participants' contributions	71	78
Benefits paid	(237)	(229)
Divestitures	0	0
Fair value of plan assets at December 31	0	0	$ 0
Funded status at December 31	$ (2,430)	$ (2,788)

Employee Benefit Plans - Sumamr

Employee Benefit Plans - Sumamry of Balance Sheet Components (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Consolidated Balance Sheet for pension and other postretirement benefit plans
Noncurrent employee benefit plans	$ (6,654)	$ (7,421)
Pension Benefits | United States
Consolidated Balance Sheet for pension and other postretirement benefit plans
Deferred charges and other assets	17	21
Accrued liabilities	(180)	(188)
Noncurrent employee benefit plans	(3,031)	(3,465)
Net amount recognized at December 31	(3,194)	(3,632)
Pension Benefits | Int’l.
Consolidated Balance Sheet for pension and other postretirement benefit plans
Deferred charges and other assets	412	448
Accrued liabilities	(66)	(100)
Noncurrent employee benefit plans	(1,024)	(1,122)
Net amount recognized at December 31	(678)	(774)
Other Benefits
Consolidated Balance Sheet for pension and other postretirement benefit plans
Deferred charges and other assets	0	0
Accrued liabilities	(175)	(174)
Noncurrent employee benefit plans	(2,255)	(2,614)
Net amount recognized at December 31	$ (2,430)	$ (2,788)

Employee Benefit Plans - Amount

Employee Benefit Plans - Amounts Recognized in Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Before tax basis amount in accumulated other comprehensive loss.
Total recognized at December 31	$ 4,448	$ 5,286
Other Benefits
Before tax basis amount in accumulated other comprehensive loss.
Net actuarial loss	(56)	207
Prior service (credit) costs	(256)	(287)
Total recognized at December 31	(312)	(80)
U.S. | Pension Benefits
Before tax basis amount in accumulated other comprehensive loss.
Net actuarial loss	3,694	4,258
Prior service (credit) costs	7	9
Total recognized at December 31	3,701	4,267
Int’l. | Pension Benefits
Before tax basis amount in accumulated other comprehensive loss.
Net actuarial loss	955	1,005
Prior service (credit) costs	104	94
Total recognized at December 31	$ 1,059	$ 1,099

Employee Benefit Plans - Accumu

Employee Benefit Plans - Accumulated Benefit Obligation in Excess of Plan Assets (Details) - Pension Benefits - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
U.S.
Pension Plans With Accumulated Benefit Obligation in Excess of Plan Assets
Projected benefit obligations	$ 11,667	$ 13,514
Accumulated benefit obligations	10,456	12,129
Fair value of plan assets	8,456	9,862
Int’l.
Pension Plans With Accumulated Benefit Obligation in Excess of Plan Assets
Projected benefit obligations	1,277	1,590
Accumulated benefit obligations	1,062	1,326
Fair value of plan assets	$ 198	$ 413

Employee Benefit Plans - Net Pe

Employee Benefit Plans - Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Changes Recognized in Comprehensive Income
Prior service (credits) costs during period	$ 26	$ 1	$ (345)
Amortization of prior service (costs) credits	13	20	(19)
Other Benefits
Net Periodic Benefit Cost
Service cost	42	32	60
Interest cost	94	95	128
Expected return on plan assets	0	0	0
Amortization of prior service costs (credits)	(28)	(28)	14
Recognized actuarial losses	15	(5)	19
Settlement losses	0	0	0
Curtailment losses (gains)	0	0	0
Total net periodic benefit cost	123	94	221
Changes Recognized in Comprehensive Income
Net actuarial (gain) loss during period	(248)	284	(430)
Amortization of actuarial loss	(15)	5	(19)
Prior service (credits) costs during period	3	0	(345)
Amortization of prior service (costs) credits	28	28	(14)
Total changes recognized in other comprehensive income	(232)	317	(808)
Recognized in Net Periodic Benefit Cost and Other Comprehensive Income	(109)	411	(587)
U.S. | Pension Benefits
Net Periodic Benefit Cost
Service cost	480	489	494
Interest cost	370	366	377
Expected return on plan assets	(636)	(597)	(723)
Amortization of prior service costs (credits)	2	(5)	(9)
Recognized actuarial losses	304	340	335
Settlement losses	411	436	511
Curtailment losses (gains)	0	0	0
Total net periodic benefit cost	931	1,029	985
Changes Recognized in Comprehensive Income
Net actuarial (gain) loss during period	151	381	690
Amortization of actuarial loss	(715)	(776)	(846)
Prior service (credits) costs during period	0	0	0
Amortization of prior service (costs) credits	(2)	5	9
Total changes recognized in other comprehensive income	(566)	(390)	(147)
Recognized in Net Periodic Benefit Cost and Other Comprehensive Income	365	639	838
Int’l. | Pension Benefits
Net Periodic Benefit Cost
Service cost	141	151	159
Interest cost	206	219	261
Expected return on plan assets	(253)	(239)	(243)
Amortization of prior service costs (credits)	10	13	14
Recognized actuarial losses	29	44	47
Settlement losses	33	2	6
Curtailment losses (gains)	3	0	0
Total net periodic benefit cost	169	190	244
Changes Recognized in Comprehensive Income
Net actuarial (gain) loss during period	12	(94)	55
Amortization of actuarial loss	(62)	(46)	(53)
Prior service (credits) costs during period	23	1	0
Amortization of prior service (costs) credits	(13)	(13)	(14)
Total changes recognized in other comprehensive income	(40)	(152)	(12)
Recognized in Net Periodic Benefit Cost and Other Comprehensive Income	$ 129	$ 38	$ 232

Employee Benefit Plans - Assump

Employee Benefit Plans - Assumptions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Effects of change in the assumed health care cost-trend rates
Effect on total service and interest cost components, 1 Percent Increase	$ 12
Effect on total service and interest cost components, 1 Percent Decrease	(10)
Effect on postretirement benefit obligation, 1 Percent Increase	197
Effect on postretirement benefit obligation, 1 Percent Decrease	$ (156)
Other Benefits
Assumptions used to determine benefit obligations:
Discount rate	4.40%	3.80%	4.30%
Assumptions used to determine net periodic benefit cost:
Discount rate for service cost	3.90%	4.60%	4.90%
Discount rate for interest cost	3.50%	3.80%	4.00%
U.S.
Assumptions used to determine benefit obligations:
Rate of compensation increase	4.50%	4.50%	4.50%
Assumptions used to determine net periodic benefit cost:
Expected return on plan assets	6.75%	6.75%	7.25%
Rate of compensation increase	4.50%	4.50%	4.50%
U.S. | Pension Benefits
Assumptions used to determine benefit obligations:
Discount rate	4.20%	3.50%	3.90%
Assumptions used to determine net periodic benefit cost:
Discount rate for service cost	3.70%	4.20%	4.40%
Discount rate for interest cost	3.00%	3.00%	3.00%
Expected return on plan assets			7.50%
U.S. | Other Benefits
Assumptions used to determine benefit obligations:
Discount rate	4.30%	3.60%	4.10%
Int’l.
Assumptions used to determine benefit obligations:
Rate of compensation increase	4.00%	4.00%	4.50%
Assumptions used to determine net periodic benefit cost:
Expected return on plan assets	5.50%	5.50%	6.30%
Rate of compensation increase	4.00%	4.50%	4.80%
Int’l. | Pension Benefits
Assumptions used to determine benefit obligations:
Discount rate	4.40%	3.90%	4.30%
Assumptions used to determine net periodic benefit cost:
Discount rate for service cost	3.90%	4.30%	5.30%
Discount rate for interest cost	3.90%	4.30%	5.30%

Employee Benefit Plans - Plan A

Employee Benefit Plans - Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	$ 129	$ 143	$ 134
U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	8,532	9,948
U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	2,965	3,663
U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,758	1,909
U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	49	54
U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	3,760	4,322
Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	4,142	4,766
Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,441	1,799
Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	642	912
Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	80	89
Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,979	1,966
U.S. | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,110	1,331
U.S. | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,110	1,331
U.S. | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
U.S. | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
U.S. | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
U.S. | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	520	652
U.S. | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	520	651
U.S. | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	1
U.S. | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
U.S. | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
International | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1	0	0
International | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,631	2,060
International | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,630	2,057
International | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1	3
International | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
International | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
International | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	521	691
International | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	520	691
International | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
International | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1	0
International | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Collective Trusts/Mutual Funds | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	893	1,089
Collective Trusts/Mutual Funds | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	21	22
Collective Trusts/Mutual Funds | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Collective Trusts/Mutual Funds | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Collective Trusts/Mutual Funds | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	872	1,067
Collective Trusts/Mutual Funds | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	152	204
Collective Trusts/Mutual Funds | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	9	19
Collective Trusts/Mutual Funds | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	4
Collective Trusts/Mutual Funds | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Collective Trusts/Mutual Funds | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	143	181
Government | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	225	274
Government | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Government | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	225	274
Government | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Government | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Government | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	254	296
Government | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	97	77
Government | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	157	219
Government | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Government | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Corporate | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	21	30	19
Corporate | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,382	1,492
Corporate | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Corporate | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,382	1,492
Corporate | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Corporate | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Corporate | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	409	593
Corporate | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Corporate | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	389	563
Corporate | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	20	30
Corporate | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Bank Loans | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	5	11	11
Bank Loans | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	119	117
Bank Loans | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Bank Loans | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	114	106
Bank Loans | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	5	11
Bank Loans | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Bank Loans | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Bank Loans | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Bank Loans | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Bank Loans | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Bank Loans | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mortgage/Asset Backed | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1	1
Mortgage/Asset Backed | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mortgage/Asset Backed | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1	1
Mortgage/Asset Backed | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mortgage/Asset Backed | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mortgage/Asset Backed | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	6	8
Mortgage/Asset Backed | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mortgage/Asset Backed | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	6	8
Mortgage/Asset Backed | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mortgage/Asset Backed | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Collective Trusts/Mutual Funds | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	877	1,130
Collective Trusts/Mutual Funds | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Collective Trusts/Mutual Funds | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Collective Trusts/Mutual Funds | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Collective Trusts/Mutual Funds | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	877	1,130
Collective Trusts/Mutual Funds | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,521	1,481
Collective Trusts/Mutual Funds | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	15	0
Collective Trusts/Mutual Funds | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	16
Collective Trusts/Mutual Funds | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Collective Trusts/Mutual Funds | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,506	1,465
Mixed Funds | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mixed Funds | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mixed Funds | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mixed Funds | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mixed Funds | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mixed Funds | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	74	80
Mixed Funds | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	3	1
Mixed Funds | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	71	79
Mixed Funds | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Mixed Funds | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Real Estate | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	56	56	60
Real Estate | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,065	1,096
Real Estate | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Real Estate | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Real Estate | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Real Estate | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	1,065	1,096
Real Estate | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	378	376
Real Estate | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Real Estate | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Real Estate | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	56	56
Real Estate | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	322	320
Alternative Investments | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	941	1,022
Alternative Investments | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Alternative Investments | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Alternative Investments | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Alternative Investments | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	941	1,022
Alternative Investments | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Alternative Investments | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Alternative Investments | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Alternative Investments | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Alternative Investments | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Cash and Cash Equivalents | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	212	260
Cash and Cash Equivalents | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	208	255
Cash and Cash Equivalents | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	4	5
Cash and Cash Equivalents | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Cash and Cash Equivalents | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Cash and Cash Equivalents | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	287	366
Cash and Cash Equivalents | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	277	362
Cash and Cash Equivalents | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	2	4
Cash and Cash Equivalents | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Cash and Cash Equivalents | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	8	0
Other | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	46	46	$ 44
Other | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	76	76
Other | U.S. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	(4)	(2)
Other | U.S. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	31	28
Other | U.S. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	44	43
Other | U.S. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	5	7
Other | Int’l.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	20	19
Other | Int’l. | Level 1
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	(2)
Other | Int’l. | Level 2
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	17	18
Other | Int’l. | Level 3
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	3	3
Other | Int’l. | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	0	0
Defined Benefit Plan, Equity Securities, Common Stock [Member] | U.S.
Fair Value Measurements of Company's Pension Plans
Fair value of plan assets	$ 9	$ 12

Employee Benefit Plans - Summ_2

Employee Benefit Plans - Summary of Change in Assets Measured at Level 3 (Details) - Level 3 - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
The effect of fair-value measurements using significant unobservable inputs on changes in Level 3 plan assets for the period are outlined below
Fair value of plan assets at January 1	$ 143	$ 134
Actual Return on Plan Assets:
Assets held at the reporting date	15	2
Assets sold during the period	(4)	0
Purchases, Sales and Settlements	(24)	10
Transfers in and/or out of Level 3	(1)	(3)
Fair value of plan assets at December 31	129	143
International
The effect of fair-value measurements using significant unobservable inputs on changes in Level 3 plan assets for the period are outlined below
Fair value of plan assets at January 1	0	0
Actual Return on Plan Assets:
Assets held at the reporting date	4	0
Assets sold during the period	(4)	0
Purchases, Sales and Settlements	0	0
Transfers in and/or out of Level 3	1	0
Fair value of plan assets at December 31	1	0
Corporate
The effect of fair-value measurements using significant unobservable inputs on changes in Level 3 plan assets for the period are outlined below
Fair value of plan assets at January 1	30	19
Actual Return on Plan Assets:
Assets held at the reporting date	(2)	1
Assets sold during the period	0	0
Purchases, Sales and Settlements	(7)	10
Transfers in and/or out of Level 3	0	0
Fair value of plan assets at December 31	21	30
Bank Loans
The effect of fair-value measurements using significant unobservable inputs on changes in Level 3 plan assets for the period are outlined below
Fair value of plan assets at January 1	11	11
Actual Return on Plan Assets:
Assets held at the reporting date	0	0
Assets sold during the period	0	0
Purchases, Sales and Settlements	(4)	3
Transfers in and/or out of Level 3	(2)	(3)
Fair value of plan assets at December 31	5	11
Real Estate
The effect of fair-value measurements using significant unobservable inputs on changes in Level 3 plan assets for the period are outlined below
Fair value of plan assets at January 1	56	60
Actual Return on Plan Assets:
Assets held at the reporting date	13	1
Assets sold during the period	0	0
Purchases, Sales and Settlements	(13)	(5)
Transfers in and/or out of Level 3	0	0
Fair value of plan assets at December 31	56	56
Other
The effect of fair-value measurements using significant unobservable inputs on changes in Level 3 plan assets for the period are outlined below
Fair value of plan assets at January 1	46	44
Actual Return on Plan Assets:
Assets held at the reporting date	0	0
Assets sold during the period	0	0
Purchases, Sales and Settlements	0	2
Transfers in and/or out of Level 3	0	0
Fair value of plan assets at December 31	$ 46	$ 46

Employee Benefit Plans - Execpe

Employee Benefit Plans - Execpected Benefit Payments (Details) $ in Millions	Dec. 31, 2018USD ($)
Other Benefits
Benefit payments, which include estimated future service, are expected to be paid by the company in the next 10years
2,019	$ 175
2,020	172
2,021	171
2,022	168
2,023	166
2024-2028	795
U.S. | Pension Benefits
Benefit payments, which include estimated future service, are expected to be paid by the company in the next 10years
2,019	1,310
2,020	1,240
2,021	1,170
2,022	1,145
2,023	1,118
2024-2028	4,972
Int’l. | Pension Benefits
Benefit payments, which include estimated future service, are expected to be paid by the company in the next 10years
2,019	271
2,020	266
2,021	577
2,022	228
2,023	234
2024-2028	$ 1,392

Other Contingencies and Commi_2

Other Contingencies and Commitments (Details)	12 Months Ended
	Dec. 31, 2018USD ($)Locationguaranty	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2009USD ($)
Guarantees
Number of guarantees | guaranty	2
Guarantee for payments under terminal use agreements	$ 968,000,000
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 2019	1,300,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2020	1,200,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2021	1,300,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2022	1,000,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2023	800,000,000
Long term unconditional purchase obligations and commitments, including throughout and take or pay agreements in 2024 and after	4,700,000,000
Total payments under long term unconditional purchase obligations and commitments including throughput and Take-or-Pay agreements	1,400,000,000	$ 1,300,000,000	$ 1,300,000,000
Environmental
Environmental reserve balance	$ 1,327,000,000
Sites with potential remediation activities (in sites) | Location	144
Sites with Potential Remediation Activities
Environmental
Environmental reserve	$ 258,000,000
Environmental Reserve Less Environmental Reserve for Sites with Potential Remediation Activities
Environmental
Environmental reserve	1,069,000,000
Other Businesses
Environmental
Environmental reserve	1,000,000
Upstream
Environmental
Environmental reserve	296,000,000
United States | Downstream
Environmental
Environmental reserve	748,000,000
International | Downstream
Environmental
Environmental reserve	24,000,000
Financing Arrangement
Guarantees
Guarantee for payments under terminal use agreements	$ 637,000,000
Term of guarantee for payments under terminal use agreement (in years)	3 years
Affiliates
Guarantees
Guarantee for payments under terminal use agreements	$ 331,000,000
Term of guarantee for payments under terminal use agreement (in years)	9 years

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Company Before Tax Obligation
Balance at January 1	$ 14,214	$ 14,243	$ 15,642
Liabilities incurred	96	684	204
Liabilities settled	(830)	(1,721)	(1,658)
Accretion expense	654	668	749
Revisions in estimated cash flows	(84)	340	(694)
Balance at December 31	14,050	$ 14,214	$ 14,243
Long-term portion of the company's before-tax asset retirement obligations	$ 12,957

Revenue (Details)

Revenue (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 01, 2018
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Taxes other than on income	[1]	$ 4,867	$ 12,331	$ 11,668
Excise and similar taxes on products and merchandise			$ 7,189	$ 6,905
Receivables		10,046			$ 9,779
Difference between Revenue Guidance in Effect before and after Topic 606 | Accounting Standards Update 2014-09
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Taxes other than on income		$ 7,861
[1]	2017 and 2016 include excise, value-added and similar taxes of $7,189 and $6,905, respectively, collected on behalf of third parties. Beginning in 2018, these taxes are netted in "Taxes other than on income" in accordance with Accounting Standards Update (ASU) 2014-09. Refer to Note 25, "Revenue" beginning on page 88.

Other Financial Information (De

Other Financial Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Mar. 31, 2018
Business Acquisition [Line Items]
Goodwill	$ 4,518	$ 4,531
Segment Reporting Information [Line Items]
Gains on sale of nonstrategic properties	630	1,800
Company share of equity affiliates foreign currency effects	416	(45)	$ 1
Total financing interest and debt costs	921	902	753
Less: Capitalized interest	173	595	552
Interest and debt expense	748	307	201
Research and development expenses	453	433	476
Excess of replacement cost over the carrying value of inventories (LIFO method)	5,134	3,937	2,942
LIFO profits (losses) on inventory drawdowns included in earnings	26	(5)	(88)
Foreign currency effects	611	(446)	$ 58
Downstream
Segment Reporting Information [Line Items]
Gains on sale of nonstrategic properties	365	850
Upstream
Segment Reporting Information [Line Items]
Gains on sale of nonstrategic properties	265	950
Gain (loss) for impairments and other assets write-offs	$ 2,000	$ 900
Unocal
Business Acquisition [Line Items]
Goodwill				$ 4,518

Schedule II - Valuation and Q_2

Schedule II - Valuation and Qualifying Accounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Employee Termination Benefits
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at January 1	$ 62	$ 111	$ 308
Additions (reductions) charged to expense	5	20	160
Payments/ reductions	(48)	(69)	(357)
Balance at December 31	19	62	111
Allowance for Doubtful Accounts
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at January 1	606	487	429
Additions (reductions) charged to expense	379	128	76
Payments/ reductions	(5)	(9)	(18)
Balance at December 31	980	606	487
Deferred Income Tax Valuation Allowance
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at January 1	16,574	16,069	15,412
Additions (reductions) charged to expense	2,000	2,681	1,810
Payments/ reductions	(2,601)	(2,176)	(1,153)
Balance at December 31	$ 15,973	$ 16,574	$ 16,069