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Document and Entity Information - USD ($)	3 Months Ended
Document and Entity Information - USD ($)	Mar. 31, 2011	Jun. 30, 2010
Document and Entity Information [Abstract]
Entity Registrant Name	CHEVRON CORP
Entity Central Index Key	0000093410
Document Type	10-Q
Document Period End Date	Mar. 31, 2011
Amendment Flag	false
Document Fiscal Year Focus	2011
Document Fiscal Period Focus	Q1
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		$ 136,438,881,628
Entity Common Stock, Shares Outstanding	2,010,270,141

Consolidated Statement of Income (Unaudited) - USD ($)
shares in Thousands, $ in Millions

3 Months Ended

Mar. 31, 2011

Mar. 31, 2010

Revenues and Other Income

Sales and other operating revenues

^[1]

$ 58,412

$ 46,741

Income from equity affiliates

1,687

1,235

Other income

242

203

Total Revenues and Other Income

60,341

48,179

Costs and Other Deductions

Purchased crude oil and products

35,201

27,144

Operating expenses

5,063

4,589

Selling, general and administrative expenses

1,100

1,042

Exploration expenses

168

180

Depreciation, depletion and amortization

3,126

3,082

Taxes other than on income

^[1]

4,561

4,472

Interest and debt expense

Total Costs and Other Deductions

49,219

40,529

Income Before Income Tax Expense

11,122

7,650

Income Tax Expense

4,883

3,070

Net Income

6,239

4,580

Less: Net income attributable to noncontrolling interests

Net Income Attributable to Chevron Corporation

$ 6,211

$ 4,552

Per Share of Common Stock:

Net Income Attributable to Chevron Corporation - Basic

$ 3.11

$ 2.28

Net Income Attributable to Chevron Corporation - Diluted

3.09

2.27

Dividends

$ 0.72

$ 0.68

Weighted Average Number of Shares Outstanding (000s)

Basic

1,994,735

1,994,983

Diluted

2,008,584

2,004,217

Includes excise, value-added and similar taxes:

$ 2,134

$ 2,072

[1]	Includes excise, value-added and similar taxes.

Consolidated Statement of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2011	Mar. 31, 2010
Consolidated Statement of Comprehensive Income [Abstract]
Net Income	$ 6,239	$ 4,580
Currency translation adjustment	33	3
Unrealized holding loss on securities:
Net loss arising during period	(1)	(1)
Derivatives:
Net derivatives gain (loss) on hedge transactions	(11)	1
Reclassification to net income of net realized gain	(1)
Income taxes on derivatives transactions	4
Total	(8)	1
Actuarial loss:
Amortization to net income of net actuarial loss	210	165
Actuarial gain arising during period	51
Prior service cost:
Amortization to net income of net prior service costs (credits)	13	(15)
Defined benefit plans sponsored by equity affiliates	12	7
Income taxes on defined benefit plans	(97)	(58)
Total	189	99
Other Comprehensive Gain, Net of Tax	213	102
Comprehensive Income	6,452	4,682
Comprehensive income attributable to noncontrolling interests	(28)	(28)
Comprehensive Income Attributable to Chevron Corporation	$ 6,424	$ 4,654

Consolidated Balance Sheet (Unaudited) - USD ($) $ in Millions	Mar. 31, 2011	Dec. 31, 2010
ASSETS
Cash and cash equivalents	$ 13,149	$ 14,060
Time deposits	3,580	2,855
Marketable securities	145	155
Accounts and notes receivable, net	22,078	20,759
Inventories:
Crude oil and petroleum products	4,213	3,589
Chemicals	406	395
Materials, supplies and other	1,613	1,509
Total inventories	6,232	5,493
Prepaid expenses and other current assets	5,667	5,519
Total Current Assets	50,851	48,841
Long-term receivables, net	2,071	2,077
Investments and advances	22,003	21,520
Properties, plant and equipment, at cost	215,560	207,367
Less: Accumulated depreciation, depletion and amortization	104,485	102,863
Properties, plant and equipment, net	111,075	104,504
Deferred charges and other assets	3,203	3,210
Goodwill	4,655	4,617
Assets held for sale	878	0
Total Assets	194,736	184,769
LIABILITIES AND EQUITY
Short-term debt	1,817	187
Accounts payable	21,011	19,259
Accrued liabilities	4,916	5,324
Federal and other taxes on income	4,106	2,776
Other taxes payable	1,463	1,466
Total Current Liabilities	33,313	29,012
Long-term debt	9,484	11,003
Capital lease obligations	274	286
Deferred credits and other noncurrent obligations	19,242	19,264
Noncurrent deferred income taxes	14,978	12,697
Reserves for employee benefit plans	6,595	6,696
Total Liabilities	83,886	78,958
Preferred stock (authorized 100,000,000 shares, $1.00 par value, none issued)	0	0
Common stock (authorized 6,000,000,000 shares, $.75 par value, 2,442,676,580 shares issued at March 31, 2011 and December 31, 2010)	1,832	1,832
Capital in excess of par value	14,931	14,796
Retained earnings	124,417	119,641
Accumulated other comprehensive loss	(4,253)	(4,466)
Deferred compensation and benefit plan trust	(299)	(311)
Treasury stock, at cost (432,406,439 and 435,195,799 shares at March 31, 2011, and December 31, 2010, respectively)	(26,528)	(26,411)
Total Chevron Corporation Stockholders' Equity	110,100	105,081
Noncontrolling interests	750	730
Total Equity	110,850	105,811
Total Liabilities and Equity	$ 194,736	$ 184,769

Consolidated Statement of Cash Flows (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2011	Mar. 31, 2010
Operating Activities
Net Income	$ 6,239	$ 4,580
Adjustments
Depreciation, depletion and amortization	3,126	3,082
Dry hole expense	2	66
Distributions more than income from equity affiliates	201	1
Net before-tax gains on asset retirements and sales	(141)	(165)
Net foreign currency effects	57	45
Deferred income tax provision	73	(104)
Net decrease in operating working capital	110	63
Decrease (increase) in long-term receivables	7	(129)
Decrease in other deferred charges	34	14
Cash contributions to employee pension plans	(171)	(306)
Other	277	370
Net Cash Provided by Operating Activities	9,814	7,517
Investing Activities
Acquisition of Atlas Energy	(3,014)
Advance to Atlas Energy	(403)
Capital expenditures	(4,645)	(3,967)
Proceeds and deposits related to asset sales	284	239
Net purchases of time deposits	(725)	(3,695)
Net sales of marketable securities	22	20
Net sales of other short-term investments	134	68
Net Cash Used for Investing Activities	(8,347)	(7,335)
Financing Activities
Net borrowings (payments) of short-term obligations	151	(72)
Repayments of long-term debt and other financing obligations	(1,069)	(25)
Cash dividends - common stock	(1,436)	(1,357)
Distributions to noncontrolling interests	(13)	(17)
Net (purchases) sales of treasury shares	(58)	40
Net Cash Used for Financing Activities	(2,425)	(1,431)
Effect of Exchange Rate Changes on Cash and Cash Equivalents	47	(91)
Net Change in Cash and Cash Equivalents	(911)	(1,340)
Cash and Cash Equivalents at January 1	14,060	8,716
Cash and Cash Equivalents at March 31	$ 13,149	$ 7,376

Information Relating to the Consolidated Statement of Cash Flows

3 Months Ended

Mar. 31, 2011

Information Relating to the Consolidated Statement of Cash Flows [Abstract]

Information Relating to the Consolidated Statement of Cash Flows


Note 3.	Information Relating to the Consolidated Statement of Cash Flows

The “Net decrease in operating working capital” was composed of the following operating changes:


	Three Months Ended March 31
	2011			2010
	(Millions of dollars)

Increase in accounts and notes receivable	$	(1,217	)	$	(233	)
Increase in inventories		(766	)		(549	)
Increase in prepaid expenses and other current assets		(298	)		(603	)
Increase in accounts payable and accrued liabilities		1,119			210
Increase in income and other taxes payable		1,272			1,238

Net decrease in operating working capital	$	110		$	63

The “Net decrease in operating working capital” includes reductions of $83 million and $8 million for excess income tax benefits associated with stock options exercised during the three months ended March 31, 2011, and 2010, respectively. These amounts are offset by an equal amount in “Net (purchases) sales of treasury shares.”

“Net Cash Provided by Operating Activities” included the following cash payments for interest on debt and for income taxes:


	Three Months Ended
	March 31
	2011		2010
	(Millions of dollars)

Interest on debt (net of capitalized interest)	$	49	$	70
Income taxes		3,017		1,885

The “Acquisition of Atlas Energy” represents the purchase price of $3.0 billion. An “Advance to Atlas Energy” of $403 million was made to facilitate the purchase of a 49 percent interest in Laurel Mountain Midstream LLC on the day of closing. The “Net decrease in operating working capital” includes $184 million for payments made in connection with Atlas equity awards subsequent to the acquisition.

The “Net purchases of time deposits” consisted of the following gross amounts:


	Three Months Ended
	March 31
	2011			2010
	(Millions of dollars)

Time deposits purchased	$	(2,480	)	$	(3,695	)
Time deposits matured		1,755			—

Net purchases of time deposits	$	(725	)	$	(3,695	)

The “Net sales of marketable securities” consisted of the following gross amounts:


	Three Months Ended
	March 31
	2011		2010
	(Millions of dollars)

Marketable securities purchased		$—		$—
Marketable securities sold		22		20

Net sales of marketable securities		$22		$20

The “Repayments of long-term debt and other financing obligations” includes $761 million for repayment of Atlas debt and $271 million for payoff of the Atlas revolving credit facility. Refer to Note 15, beginning on page 21, for additional discussion of the Atlas acquisition.

The “Net (purchases) sales of treasury shares” represents the cost of common shares acquired less the cost of shares issued for share-based compensation plans. Purchases totaled $756 million and $10 million in the first three months of 2011 and 2010, respectively. During first quarter 2011, the company purchased 7.6 million common shares for $750 million under its ongoing share repurchase program. No purchases were made under the company’s stock repurchase program in first quarter 2010.

The major components of “Capital expenditures” and the reconciliation of this amount to the capital and exploratory expenditures, including equity affiliates, are as follows:


	Three Months Ended
	March 31
	2011			2010
	(Millions of dollars)

Additions to properties, plant and equipment	$	4,471		$	3,770
Additions to investments		217			150
Current year dry hole expenditures		2			62
Payments for other liabilities and assets, net		(45	)		(15	)

Capital expenditures		4,645			3,967
Expensed exploration expenditures		166			114
Assets acquired through capital lease obligations		1			3

Capital and exploratory expenditures, excluding equity affiliates		4,812			4,084
Company’s share of expenditures by equity affiliates		234			298

Capital and exploratory expenditures, including equity affiliates	$	5,046		$	4,382

Operating Segments and Geographic Data

3 Months Ended

Mar. 31, 2011

Operating Segments and Geographic Data [Abstract]

Operating Segments and Geographic Data


Note 4.	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” as defined in accounting standards for segment reporting (ASC 280). 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 project. 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 mining operations, power generation businesses, worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities, energy services, and alternative fuels and technology.

The segments are separately managed for investment purposes under a structure that includes “segment managers” who report to the company’s “chief operating decision maker” (CODM) (terms as defined in ASC 280). The CODM is the company’s Executive Committee (EXCOM), a committee of senior officers that includes the Chief Executive Officer, and EXCOM reports to the Board of Directors of Chevron Corporation.

The operating segments represent components of the company, as described in accounting standards for segment reporting (ASC 280), 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.

Segment managers for the reportable segments are directly accountable to and maintain regular contact with the company’s CODM to discuss the segment’s operating activities and financial performance. The CODM approves annual capital and exploratory budgets at the reportable segment level, as well as reviews capital and exploratory funding for major projects and approves major changes to the annual capital and exploratory budgets. However, business-unit managers within the operating segments are directly responsible for decisions relating to project implementation and all other matters connected with daily operations. Company officers who are members of the EXCOM also have individual management responsibilities and participate in other committees for purposes other than acting as the CODM.

The company’s primary country of operation is the United States of America, its country of domicile. Other components of the company’s operations are reported as “International” (outside the United States).

Segment Earnings The company evaluates the performance of its operating segments on an after-tax basis, without considering the effects of debt financing interest expense or investment interest income, both of which are managed by the company on a worldwide basis. Corporate administrative costs and assets are not allocated to the operating segments. However, operating segments are billed for the direct use of corporate services. Nonbillable costs remain at the corporate level in “All Other.” Earnings by major operating area for the three-month periods ended March 31, 2011 and 2010 are presented in the following table:


	Three Months Ended
	March 31
Segment Earnings	2011			2010
	(Millions of dollars)

Upstream
United States		$1,449			$1,156
International		4,528			3,568

Total Upstream		5,977			4,724

Downstream
United States		442			82
International		180			114

Total Downstream		622			196

Total Segment Earnings		6,599			4,920

All Other
Interest Expense		—			(16	)
Interest Income		18			10
Other		(406	)		(362	)

Net Income Attributable to Chevron Corporation		$6,211			$4,552

Segment Assets Segment assets do not include intercompany investments or intercompany receivables. “All Other” assets consist primarily of worldwide cash, cash equivalents, time deposits and marketable securities; real estate; information systems; mining operations; power generation businesses; alternative fuels; technology companies; and assets of the corporate administrative functions. Segment assets at March 31, 2011, and December 31, 2010, are as follows:


	At March 31		At December 31
Segment Assets	2011		2010
	(Millions of dollars)

Upstream
United States		$ 32,648		$ 26,319
International		91,016		89,306
Goodwill		4,655		4,617

Total Upstream		128,319		120,242

Downstream
United States		21,974		21,406
International		22,492		20,559

Total Downstream		44,466		41,965

Total Segment Assets		172,785		162,207

All Other
United States		10,803		11,125
International		11,148		11,437

Total All Other		21,951		22,562

Total Assets — United States		65,425		58,850
Total Assets — International		124,656		121,302
Goodwill		4,655		4,617

Total Assets		$194,736		$184,769

Segment Sales and Other Operating Revenues Segment sales and other operating revenues, including internal transfers, for the three-month periods ended March 31, 2011 and 2010 are presented in the following table. 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 mining operations, power generation businesses, insurance operations, real estate activities and technology companies.

Sales and Other Operating Revenues


	Three Months Ended March 31
	2011			2010
	(Millions of dollars)

Upstream
United States	$	6,666		$	6,593
International		12,869			9,548

Subtotal		19,535			16,141
Intersegment Elimination — United States		(4,265	)		(3,473	)
Intersegment Elimination — International		(8,453	)		(5,705	)

Total Upstream		6,817			6,963

Downstream
United States		21,434			17,718
International		30,057			21,967

Subtotal		51,491			39,685
Intersegment Elimination — United States		(20	)		(28	)
Intersegment Elimination — International		(20	)		(22	)

Total Downstream		51,451			39,635

All Other
United States		365			294
International		10			15

Subtotal		375			309
Intersegment Elimination — United States		(222	)		(159	)
Intersegment Elimination — International		(9	)		(7	)

Total All Other		144			143

Sales and Other Operating Revenues
United States		28,465			24,605
International		42,936			31,530

Subtotal		71,401			56,135
Intersegment Elimination — United States		(4,507	)		(3,660	)
Intersegment Elimination — International		(8,482	)		(5,734	)

Total Sales and Other Operating Revenues	$	58,412		$	46,741

Employee Benefit

3 Months Ended

Mar. 31, 2011

Employee Benefit Abstract]

Employee Benefit


Note 8.	Employee Benefits

Chevron 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 (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 the retirees share the costs. Medical coverage for Medicare-eligible retirees in the company’s main U.S. medical plan is secondary to Medicare (including Part D), and the increase to the company contribution for retiree medical coverage is limited to no more than 4 percent each year. Certain life insurance benefits are paid by the company.

The components of net periodic benefit cost for 2011 and 2010 are as follows:


	Three Months Ended March 31
	2011			2010
	(Millions of dollars)

Pension Benefits
United States
Service cost	$	94		$	84
Interest cost		116			122
Expected return on plan assets		(153	)		(135	)
Amortization of prior service credits		(2	)		(2	)
Amortization of actuarial losses		77			80
Settlement losses		91			55

Total United States		223			204

International
Service cost		45			36
Interest cost		82			73
Expected return on plan assets		(71	)		(58	)
Amortization of prior service costs		6			5
Amortization of actuarial losses		26			24
Curtailment losses		27			—

Total International		115			80

Net Periodic Pension Benefit Cost	$	338		$	284

Other Benefits*
Service cost	$	14		$	10
Interest cost		45			43
Amortization of prior service credits		(18	)		(18	)
Amortization of actuarial losses		16			6

Net Periodic Other Benefit Cost	$	57		$	41


*		Includes costs for U.S. and international OPEB plans. Obligations for plans outside the U.S. are not significant relative to the company’s total OPEB obligation.

At the end of 2010, the company estimated it would contribute $950 million to employee pension plans during 2011 (composed of $650 million for the U.S. plans and $300 million for the international plans). Through March 31, 2011, a total of $171 million was contributed (including $117 million to the U.S. plans). Total estimated contributions for the full year continue to be $950 million, but the company may contribute an amount that differs from this estimate. Actual contribution amounts are dependent upon plan investment returns, changes in pension obligations, regulatory environments and other economic factors. Additional funding may ultimately be required if investment returns are insufficient to offset increases in plan obligations.

During the first three months of 2011, the company contributed $49 million to its OPEB plans. The company anticipates contributing about $176 million during the remainder of 2011.

Litigation

3 Months Ended

Mar. 31, 2011

Litigation [Abstract]

Litigation


Note 9.	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 20 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, but could be material to net income in any one period. The company no longer uses MTBE in the manufacture of gasoline in the United States.

Ecuador Chevron is a defendant in a civil lawsuit before the Superior Court of Nueva Loja in Lago Agrio, Ecuador, brought 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 million. 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.

In 2008, a mining engineer appointed by the court to identify and determine the cause of environmental damage, and to specify steps needed to remediate it, issued a report recommending that the court assess $18.9 billion, which would, according to the engineer, provide financial compensation for purported damages, including wrongful death claims, and pay for, among other items, environmental remediation, health care systems and additional infrastructure for Petroecuador. The engineer’s report also asserted that an additional $8.4 billion could be assessed against Chevron for unjust enrichment. In 2009, following the disclosure by Chevron of evidence that the judge participated in meetings in which businesspeople and individuals holding themselves out as government officials discussed the case and its likely outcome, the judge presiding over the case was recused. In 2010, Chevron moved to strike the mining engineer’s report and to dismiss the case based on evidence obtained through discovery in the United States indicating that the report was prepared by consultants for the plaintiffs before being presented as the mining engineer’s independent and impartial work and showing further evidence of misconduct. In August 2010, the judge issued an order stating that he was not bound by the mining engineer’s report and requiring the parties to provide their positions on damages within 45 days. Chevron subsequently petitioned for recusal of the judge, claiming that he had disregarded evidence of fraud and misconduct and that he had failed to rule on a number of motions within the statutory time requirement.

In September 2010, Chevron submitted its position on damages, asserting that no amount should be assessed against it. The plaintiffs’ submission, which relied in part on the mining engineer’s report, took the position that damages are between approximately $16 billion and $76 billion and that unjust enrichment should be assessed in an amount between approximately $5 billion and $38 billion. The next day, the judge issued an order closing the evidentiary phase of the case and notifying the parties that he had requested the case file so that he could prepare a judgment. Chevron petitioned to have that order declared a nullity in light of Chevron’s prior recusal petition, and because procedural and evidentiary matters remain unresolved. In October 2010, Chevron’s motion to recuse the judge was granted. A new judge took charge of the case and revoked the prior judge’s order closing the evidentiary phase of the case. On December 17, 2010, the judge issued an order closing the evidentiary phase of the case and notifying the parties that he had requested the case file so that he could prepare a judgment.

Chevron and Texpet filed an arbitration claim in September 2009 against the Republic of Ecuador before the Permanent Court of Arbitration in The Hague under the Rules of the United Nations Commission on International Trade Law. The claim alleges violations of the Republic of Ecuador’s obligations under the United States-Ecuador Bilateral Investment Treaty (BIT) and breaches of the settlement and release agreements between the Republic of Ecuador and Texpet (described above), which are investment agreements protected by the BIT. Through the arbitration, Chevron and Texpet are seeking relief against the Republic of Ecuador, including a declaration that any judgment against Chevron in the Lago Agrio litigation constitutes a violation of Ecuador’s obligations under the BIT. On February 9, 2011, the Permanent Court of Arbitration issued an Order for Interim Measures requiring the Republic of Ecuador to take all measures at its disposal to suspend or cause to be suspended the enforcement or recognition within and without Ecuador of any judgment against Chevron in the Lago Agrio case pending further order of the Tribunal. Chevron expects to continue seeking permanent injunctive relief and monetary relief before the Tribunal.

Through a series of recent U.S. court proceedings initiated by Chevron to obtain discovery relating to the Lago Agrio litigation and the BIT arbitration, Chevron has obtained evidence that it believes shows a pattern of fraud, collusion, corruption, and other misconduct on the part of several lawyers, consultants and others acting for the Lago Agrio plaintiffs. In February 2011, Chevron filed a civil lawsuit in the Federal District Court for the Southern District of New York against the Lago Agrio plaintiffs and several of their lawyers, consultants and supporters alleging violations of the Racketeer Influenced and Corrupt Organizations Act and other state laws. Through the civil lawsuit, Chevron is seeking relief that includes an award of damages and a declaration that any judgment against Chevron in the Lago Agrio litigation is the result of fraud and other unlawful conduct and is therefore unenforceable. On March 7, 2011, the Court issued a preliminary injunction prohibiting the Lago Agrio plaintiffs and persons acting in concert with them from taking any action in furtherance of recognition or enforcement of any judgment against Chevron in the Lago Agrio case pending resolution of Chevron’s civil lawsuit by the Court. The Court has set a trial date of November 14, 2011 for Chevron’s claim for declaratory relief.

On February 14, 2011, the Provincial Court in Lago Agrio rendered an adverse judgment in the case. The Provincial Court rejected Chevron’s defenses to the extent the Court addressed them in its opinion. The judgment assessed approximately $8.6 billion in damages and approximately $0.9 billion as an award for the plaintiffs’ representatives. It also assessed an additional amount of approximately $8.6 billion in punitive damages unless the company issued a public apology within fifteen 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. Chevron continues to believe the Court’s judgment is illegitimate and unenforceable in Ecuador, the United States and other countries. The company also believes the judgment is the product of fraud, and contrary to the legitimate scientific evidence. Chevron cannot predict the timing or ultimate outcome of the appeals process in Ecuador. Chevron will continue a vigorous defense of any imposition of liability. Because Chevron has no substantial assets in Ecuador, Chevron would expect enforcement actions as a result of this judgment to be brought in other jurisdictions. Chevron expects to contest any such actions.

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 judgment, the 2008 engineer’s report and the September 2010 plaintiffs’ submission, management does not believe these documents have any utility in calculating a reasonably possible loss (or a range of loss). Moreover, the highly uncertain legal environment surrounding the case provides no basis for management to estimate a reasonably possible loss (or a range of loss).

Other Contingencies and Commitments

3 Months Ended

Mar. 31, 2011

Other Contingencies and Commitments [Abstract]

Other Contingencies and Commitments


Note 10.	Other Contingencies and Commitments

Guarantees The company and its subsidiaries have certain other contingent liabilities with respect to guarantees, direct or indirect, of debt of affiliated companies or third parties. Under the terms of the guarantee arrangements, generally the company would be required to perform should the affiliated company or third party fail to fulfill its obligations under the arrangements. In some cases, the guarantee arrangements may have recourse provisions that would enable the company to recover any payments made under the terms of the guarantees from assets provided as collateral.

Off-Balance-Sheet Obligations The company and its subsidiaries have certain other contingent liabilities with respect to long-term unconditional purchase obligations and commitments, including throughput and take-or-pay agreements, some of which relate to suppliers’ financing arrangements. The agreements typically provide goods and services, such as pipeline and storage capacity, drilling rigs, utilities, and petroleum products, to be used or sold in the ordinary course of the company’s business.

Indemnifications The company provided certain indemnities of contingent liabilities of Equilon and Motiva to Shell and Saudi Refining, Inc., in connection with the February 2002 sale of the company’s interests in those investments. The company would be required to perform if the indemnified liabilities become actual losses. Were that to occur, the company could be required to make future payments up to $300 million. Through the end of March 2011, the company had paid $48 million under these indemnities and continues to be obligated for possible additional indemnification payments in the future.

The company has also provided indemnities relating to contingent environmental liabilities related to assets originally contributed by Texaco to the Equilon and Motiva joint ventures and environmental conditions that existed prior to the formation of Equilon and Motiva or that occurred during the period of Texaco’s ownership interest in the joint ventures. In general, the environmental conditions or events that are subject to these indemnities must have arisen prior to December 2001. Claims had to be asserted by February 2009 for Equilon indemnities and must be asserted no later than February 2012 for Motiva indemnities. Under the terms of these indemnities, there is no maximum limit on the amount of potential future payments. The company posts no assets as collateral and has made no payments under the indemnities.

The amounts payable for the indemnities described in the preceding paragraph are to be net of amounts recovered from insurance carriers and others and net of liabilities recorded by Equilon or Motiva prior to September 30, 2001, for any applicable incident.

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 million, which had been reached at December 31, 2009. Under the indemnification agreement, after reaching the $200 million 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.

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 sites, including, but not limited to, federal Superfund sites and analogous sites under state laws, refineries, crude oil fields, service stations, terminals, land development areas, and mining operations, whether operating, closed or divested. These 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.

Although the company has provided for known environmental obligations 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. Also, the company does not believe its obligations to make such expenditures have had, or will have, any significant impact on the company’s competitive position relative to other U.S. or international petroleum or chemical companies.

Equity Redetermination For crude oil and natural gas producing operations, ownership agreements may provide for periodic reassessments of equity interests in estimated crude oil and natural gas reserves. These activities, individually or together, may result in gains or losses that could be material to earnings in any given period. One such equity redetermination process has been under way since 1996 for Chevron’s interests in four producing zones at the Naval Petroleum Reserve at Elk Hills, California, for the time when the remaining interests in these zones were owned by the U.S. Department of Energy (DOE). In April 2011, Chevron and the DOE finalized an agreement to resolve all equity redetermination issues. The company does not expect any material impact to its financial position, results of operations or liquidity as a result of the settlement with the DOE.

Other Contingencies On April 26, 2010, a California appeals court issued a ruling related to the adequacy of an Environmental Impact Report (EIR) supporting the issuance of certain permits by the city of Richmond, California, to replace and upgrade certain facilities at Chevron’s refinery in Richmond. Settlement discussions with plaintiffs in the case ended late fourth quarter 2010, and on March 3, 2011, the trial court entered a judgment and peremptory writ ordering the city to set aside the project EIR and conditional use permits and enjoining Chevron from any further work. The company continues to evaluate its options going forward, which may include requesting the city to revise the EIR to address the issues identified by the Court of Appeal or other actions. Management believes the outcomes associated with the potential options for the project are uncertain. Due to the uncertainty of the company’s future course of action, or potential outcomes of any action or combination of actions, management does not believe an estimate of the financial effects, if any, of the ruling can be made at this time. However, the company’s ultimate exposure may be significant to net income in any one future period.

Chevron receives claims from and submits claims to customers; trading partners; U.S. federal, state and local regulatory bodies; governments; contractors; insurers; and suppliers. The amounts of these claims, individually and in the aggregate, may be significant and take lengthy periods to resolve.

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 gains or losses in future periods.

Fair Value Measurements

3 Months Ended

Mar. 31, 2011

Fair Value Measurements [Abstract]

Fair Value Measurements


Note 11.	Fair Value Measurements

Accounting standards for fair value measurement (ASC 820) establish a framework for measuring fair value and stipulate disclosures about fair value measurements. The standards apply to recurring and nonrecurring financial and nonfinancial assets and liabilities that require or permit fair value measurements. Among the required disclosures is the fair value hierarchy of inputs the company uses to value an asset or a liability. The three levels of the fair value hierarchy are described as follows:

Level 1: Quoted prices (unadjusted) in active markets for identical assets and liabilities. For the company, Level 1 inputs include exchange-traded futures contracts for which the parties are willing to transact at the exchange-quoted price and marketable securities that are actively traded.

Level 2: Inputs other than Level 1 that are observable, either directly or indirectly. For the company, Level 2 inputs include quoted prices for similar assets or liabilities, prices obtained through third-party broker quotes and prices that can be corroborated with other observable inputs for substantially the complete term of a contract.

Level 3: Unobservable inputs. The company does not use Level 3 inputs for any of its recurring fair value measurements. Level 3 inputs may be required for the determination of fair value associated with certain nonrecurring measurements of nonfinancial assets and liabilities. In 2010, the company used Level 3 inputs to determine the fair value of certain nonrecurring nonfinancial assets.

The fair value hierarchy for recurring assets and liabilities measured at fair value at March 31, 2011 and December 31, 2010, is as follows:

Assets and Liabilities Measured at Fair Value on a Recurring Basis
(Millions of dollars)


	At March 31, 2011								At December 31, 2010
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3

Marketable Securities		$145		$145		$ —		$—		$155		$155		$ —		$—
Derivatives		117		6		111		—		122		11		111		—

Total Assets at Fair Value		$262		$151		$111		$—		$277		$166		$111		$—

Derivatives		$286		$256		$ 30		$—		$171		$ 75		$ 96		$—

Total Liabilities at Fair Value		$286		$256		$ 30		$—		$171		$ 75		$ 96		$—

Marketable Securities The company calculates fair value for its marketable securities based on quoted market prices for identical assets and liabilities. The fair values reflect the cash that would have been received if the instruments were sold at March 31, 2011.

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 virtually all the offsetting amount to the Consolidated Statement of Income. For derivatives with identical or similar provisions as contracts that are publicly traded on a regular basis, the company uses the market values of the publicly traded instruments as an input for fair value calculations.

The company’s derivative instruments principally include crude oil, natural gas and refined product futures, swaps, options and forward contracts. 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. The company incorporates internal review, evaluation and assessment procedures, including a comparison of Level 2 fair values derived from the company’s internally developed forward curves (on a sample basis) with the pricing information to document reasonable, logical and supportable fair value determinations and proper level of classification.

The fair-value hierarchy for nonrecurring assets and liabilities measured at fair value at March 31, 2011 is as follows:

Assets and Liabilities Measured at Fair Value on a Non-Recurring Basis
(Millions of dollars)


	Three Months Ended March 31, 2011
	Total		Level 1		Level 2		Level 3		Before-Tax Loss

Properties, plant and equipment, net (held and used)		$—		$—		$—		$—		$—
Properties, plant and equipment, net (held for sale)		3		—		3		—		10
Investments and advances		—		—		—		—		2

Total Assets at Fair Value		$ 3		$—		$ 3		$—		$12

Impairments of “Properties, plant and equipment” Before-tax losses associated with the impairment of property, plant and equipment “held for sale” in the first quarter 2011 were $10 million. The company did not have any long- lived assets measured at fair value on a nonrecurring basis to report in the first quarter 2010. The losses in the current period were the result of bids received from prospective buyers of assets held for sale.

Impairments of “Investments and advances” During first quarter 2011 investments with carrying amounts of $2 million were written down to fair values of $0, resulting in before-tax losses of $2 million. The company did not have any investments and advances measured at fair value on a nonrecurring basis to report in the first quarter 2010. The fair values were determined using discount rates consistent with those used by the company to evaluate cash flows of other investments of a similar nature.

Assets and Liabilities Not Required to be Measured at Fair Value The company holds cash equivalents and bank 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 $13.1 billion and $14.1 billion at March 31, 2011 and December 31, 2010, respectively. The instruments held in “Time deposits” are bank time deposits with maturities greater than 90 days and had carrying/fair values of $3.6 billion and $2.9 billion at March 31, 2011 and December 31, 2010, respectively. The fair values of cash, cash equivalents and bank time deposits reflect the cash that would have been received if the instruments were settled at March 31, 2011.

“Cash and cash equivalents” do not include investments with a carrying/fair value of $721 million and $855 million at March 31, 2011 and December 31, 2010, respectively. At March 31, 2011, these investments include restricted funds related to various U.S. refinery projects, which are reported in “Deferred charges and other assets” on the Consolidated Balance Sheet. Long-term debt of $5.6 billion at March 31, 2011 and December 31, 2010 had estimated fair values of $6.1 billion and $6.3 billion, respectively.

The carrying values of short-term financial assets and liabilities on the balance sheet approximate their fair values. Fair values of other financial instruments at March 31, 2011 and 2010 were not material.

Acquisition of Atlas Energy Inc.

3 Months Ended

Mar. 31, 2011

Acquisition of Atlas Energy, Inc. [Abstract]

Acquisition of Atlas Energy, Inc.


Note 15.	Acquisition of Atlas Energy, Inc.

On February 17, 2011, the company acquired Atlas Energy, Inc. (Atlas), which holds one of the premier acreage positions in the Marcellus Shale, concentrated in southwestern Pennsylvania. The aggregate purchase price of Atlas was approximately $4.5 billion, which included approximately $3.0 billion cash for all the common shares of Atlas, a $403 million cash advance to facilitate Atlas’ purchase of a 49 percent interest in Laurel Mountain Midstream LLC and about $1.1 billion of assumed debt. Subsequent to the close of the transaction, the company paid off the assumed debt and made payments of $184 million in connection with Atlas equity awards.

The acquisition was accounted for as a business combination (ASC 805) which, among other things, requires assets acquired and liabilities assumed to be measured at their acquisition date fair values. Provisional fair value measurements were made in the first quarter 2011 for acquired assets and assumed liabilities, and adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date as information necessary to complete the analysis is obtained. The company expects the measurement process will be finalized by the end of 2011.

Proforma financial information is not presented as it would not be materially different from the information presented in the Consolidated Statement of Income.

The following table summarizes the provisional measurement of the assets acquired and liabilities assumed:


	At February 17, 2011
	(Millions of dollars)

Current assets		$ 150
Investments and long-term receivables		456
Properties		6,051
Goodwill		39
Other assets		5

Total assets acquired		6,701

Current liabilities		(560	)
Long-term debt and capital leases		(761	)
Deferred income taxes		(1,918	)
Other liabilities		(25	)

Total liabilities assumed		(3,264	)


Net assets acquired		$ 3,437

Properties were measured primarily using an income approach. The fair values of the acquired oil and gas properties were based on significant inputs not observable in the market, and thus represent Level 3 measurements. Significant inputs included estimated resource volumes, assumed future production profiles, estimated future commodity prices, a discount rate of 8 percent, and assumptions on the timing and amount of future operating and development costs. All the properties are in the United States and are included in the Upstream segment.

The acquisition date fair value of the consideration transferred was $3.4 billion in cash. The $39 million of goodwill was assigned to the Upstream segment and represents the amount of the consideration transferred in excess of the values assigned to the individual assets acquired and liabilities assumed. Goodwill represents the future economic benefits arising from other assets acquired that could not be individually identified and separately recognized. None of the goodwill is deductible for tax purposes. Goodwill recorded in the acquisition is not subject to amortization, but will be tested periodically for impairment as required by the applicable accounting standard (ASC 350).

Interim Financial Statements (Policies)	3 Months Ended
Interim Financial Statements (Policies)	Mar. 31, 2011
Interim Financial Statements (Policies) [Abstract]
Accounting standards for segment reporting (ASC 280)	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” as defined in accounting standards for segment reporting (ASC 280). 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 project. 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 mining operations, power generation businesses, worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities, energy services, and alternative fuels and technology.
Accounting Standards for Fair Value Measurement (ASC 820)	Accounting standards for fair value measurement (ASC 820) establish a framework for measuring fair value and stipulate disclosures about fair value measurements. The standards apply to recurring and nonrecurring financial and nonfinancial assets and liabilities that require or permit fair value measurements. Among the required disclosures is the fair value hierarchy of inputs the company uses to value an asset or a liability. The three levels of the fair value hierarchy are described as follows:
Acquisition accounted as business combination (ASC 805)	The acquisition was accounted for as a business combination (ASC 805) which, among other things, requires assets acquired and liabilities assumed to be measured at their acquisition date fair values. Provisional fair value measurements were made in the first quarter 2011 for acquired assets and assumed liabilities, and adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date as information necessary to complete the analysis is obtained. The company expects the measurement process will be finalized by the end of 2011.
Goodwill and other (ASC 350)	The acquisition date fair value of the consideration transferred was $3.4 billion in cash. The $39 million of goodwill was assigned to the Upstream segment and represents the amount of the consideration transferred in excess of the values assigned to the individual assets acquired and liabilities assumed. Goodwill represents the future economic benefits arising from other assets acquired that could not be individually identified and separately recognized. None of the goodwill is deductible for tax purposes. Goodwill recorded in the acquisition is not subject to amortization, but will be tested periodically for impairment as required by the applicable accounting standard (ASC 350).

Information Relating to the Consolidated Statement of Cash Flows (Tables)

3 Months Ended

Mar. 31, 2011

Information Relating to the Consolidated Statement of Cash Flows (Tables) [Abstract]

Net increase in operating working capital


	Three Months Ended March 31
	2011			2010
	(Millions of dollars)

Increase in accounts and notes receivable	$	(1,217	)	$	(233	)
Increase in inventories		(766	)		(549	)
Increase in prepaid expenses and other current assets		(298	)		(603	)
Increase in accounts payable and accrued liabilities		1,119			210
Increase in income and other taxes payable		1,272			1,238

Net decrease in operating working capital	$	110		$	63

Net Cash Provided by Operating Activities


	Three Months Ended
	March 31
	2011		2010
	(Millions of dollars)

Interest on debt (net of capitalized interest)	$	49	$	70
Income taxes		3,017		1,885

Net purchases of time deposits


	Three Months Ended
	March 31
	2011			2010
	(Millions of dollars)

Time deposits purchased	$	(2,480	)	$	(3,695	)
Time deposits matured		1,755			—

Net purchases of time deposits	$	(725	)	$	(3,695	)

Net sales of marketable securities


	Three Months Ended
	March 31
	2011		2010
	(Millions of dollars)

Marketable securities purchased		$—		$—
Marketable securities sold		22		20

Net sales of marketable securities		$22		$20

Capital expenditures


	Three Months Ended
	March 31
	2011			2010
	(Millions of dollars)

Additions to properties, plant and equipment	$	4,471		$	3,770
Additions to investments		217			150
Current year dry hole expenditures		2			62
Payments for other liabilities and assets, net		(45	)		(15	)

Capital expenditures		4,645			3,967
Expensed exploration expenditures		166			114
Assets acquired through capital lease obligations		1			3

Capital and exploratory expenditures, excluding equity affiliates		4,812			4,084
Company’s share of expenditures by equity affiliates		234			298

Capital and exploratory expenditures, including equity affiliates	$	5,046		$	4,382

Operating Segments and Geographic Data (Tables)

3 Months Ended

Mar. 31, 2011

Operating Segments and Geographic Data (Tables) [Abstract]

Segment Earnings


	Three Months Ended
	March 31
Segment Earnings	2011			2010
	(Millions of dollars)

Upstream
United States		$1,449			$1,156
International		4,528			3,568

Total Upstream		5,977			4,724

Downstream
United States		442			82
International		180			114

Total Downstream		622			196

Total Segment Earnings		6,599			4,920

All Other
Interest Expense		—			(16	)
Interest Income		18			10
Other		(406	)		(362	)

Net Income Attributable to Chevron Corporation		$6,211			$4,552

Segment Assets


	At March 31		At December 31
Segment Assets	2011		2010
	(Millions of dollars)

Upstream
United States		$ 32,648		$ 26,319
International		91,016		89,306
Goodwill		4,655		4,617

Total Upstream		128,319		120,242

Downstream
United States		21,974		21,406
International		22,492		20,559

Total Downstream		44,466		41,965

Total Segment Assets		172,785		162,207

All Other
United States		10,803		11,125
International		11,148		11,437

Total All Other		21,951		22,562

Total Assets — United States		65,425		58,850
Total Assets — International		124,656		121,302
Goodwill		4,655		4,617

Total Assets		$194,736		$184,769

Sales and Other Operating Revenues

Sales and Other Operating Revenues


	Three Months Ended March 31
	2011			2010
	(Millions of dollars)

Upstream
United States	$	6,666		$	6,593
International		12,869			9,548

Subtotal		19,535			16,141
Intersegment Elimination — United States		(4,265	)		(3,473	)
Intersegment Elimination — International		(8,453	)		(5,705	)

Total Upstream		6,817			6,963

Downstream
United States		21,434			17,718
International		30,057			21,967

Subtotal		51,491			39,685
Intersegment Elimination — United States		(20	)		(28	)
Intersegment Elimination — International		(20	)		(22	)

Total Downstream		51,451			39,635

All Other
United States		365			294
International		10			15

Subtotal		375			309
Intersegment Elimination — United States		(222	)		(159	)
Intersegment Elimination — International		(9	)		(7	)

Total All Other		144			143

Sales and Other Operating Revenues
United States		28,465			24,605
International		42,936			31,530

Subtotal		71,401			56,135
Intersegment Elimination — United States		(4,507	)		(3,660	)
Intersegment Elimination — International		(8,482	)		(5,734	)

Total Sales and Other Operating Revenues	$	58,412		$	46,741

Noncontrolling Interests (Details) - USD ($) $ in Millions	3 Months Ended
Noncontrolling Interests (Details) - USD ($) $ in Millions	Mar. 31, 2011	Mar. 31, 2010
Activity for equity attributable to noncontrolling interests
Beginning Balance	$ 105,811	$ 92,561
Net Income	6,239	4,580
Dividends	(1,436)	(1,357)
Minority Distributions to noncontrolling interest	(13)	(17)
Treasury shares, net	(117)	53
Other changes, net	366	232
Ending Balance	110,850	96,052
Chevron Corporation Stockholders' Equity [Member]
Activity for equity attributable to noncontrolling interests
Beginning Balance	105,081	91,914
Net Income	6,211	4,552
Dividends	(1,436)	(1,357)
Treasury shares, net	(117)	53
Other changes, net	361	187
Ending Balance	110,100	95,349
Noncontrolling Interest [Member]
Activity for equity attributable to noncontrolling interests
Beginning Balance	730	647
Net Income	28	28
Minority Distributions to noncontrolling interest	(13)	(17)
Other changes, net	5	45
Ending Balance	$ 750	$ 703

Information Relating to the Consolidated Statement of Cash Flows (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2011	Mar. 31, 2010	Feb. 17, 2011
Net decrease (increase) in operating working capital
Increase in accounts and notes receivable	$ (1,217)	$ (233)
Increase in inventories	(766)	(549)
Increase in prepaid expenses and other current assets	(298)	(603)
Increase in accounts payable and accrued liabilities	1,119	210
Increase in income and other taxes payable	1,272	1,238
Net decrease in operating working capital	110	63
Net Cash Provided by Operating Activities
Interest on debt (net of capitalized interest)	49	70
Income taxes	3,017	1,885
Net purchases of time deposits
Time deposits purchased	(2,480)	(3,695)
Time deposits matured	1,755	0
Net purchases of time deposits	(725)	(3,695)
Net sales of marketable securities
Marketable securities purchased	0
Marketable Securities Sold	22	20
Net sales of marketable securities	22	20
Capital expenditures
Additions to properties, plant and equipment	4,471	3,770
Additions to investments	217	150
Current year dry hole expenditures	2	62
Payments for other liabilities and assets, net	(45)	(15)
Capital expenditures	4,645	3,967
Expensed exploration expenditures	166	114
Assets acquired through capital lease obligations	1	3
Capital and exploratory expenditures, excluding equity affiliates	4,812	4,084
Company's share of expenditures by equity affiliates	234	298
Capital and exploratory expenditures, including equity affiliates	5,046	4,382
Information Relating to the Consolidated Statement of Cash Flows (Textuals) [Abstract]
Reduction for income tax benefits associated with stock options exercised	83	8
Purchases of treasury shares	$ 756	$ 10
Common share purchase	7.6
Share repurchase value	$ 750
Laurel Mountain Midstream LLC [Member]
Additional Information Relating to the Consolidated Statement of Cash Flows (Textuals) [Abstract]
Advance to Atlas Energy	$ 403
Purchase of Interest in Laurel Mountain Midstream	49.00%		49.00%
Atlas Energy Inc [Member]
Additional Information Relating to the Consolidated Statement of Cash Flows (Textuals) [Abstract]
Acquisition of Atlas Energy purchase price	$ 3,000		$ 3,000
Advance to Atlas Energy	403
Cash payment of equity awards included in net decrease in operating working capital	184
Repayment of Atlas debt	761
Payoff of Atlas revolving credit facility	$ 271

Operating Segments and Geographic Data (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2011	Mar. 31, 2010
Segment Earnings
Total Segment Earnings	$ 6,599	$ 4,920
Net Income Attributable to Chevron Corporation	6,211	4,552
Upstream [Member]
Segment Earnings
United States	1,449	1,156
International	4,528	3,568
Total Segment Earnings	5,977	4,724
Downstream [Member]
Segment Earnings
United States	442	82
International	180	114
Total Segment Earnings	622	196
All Other [Member]
Segment Earnings
Interest Expense		(16)
Interest Income	18	10
Other	$ (406)	$ (362)

Operating Segments and Geographic Data (Details 1) - USD ($) $ in Millions	Mar. 31, 2011	Dec. 31, 2010
Segment Assets
Goodwill	$ 4,655	$ 4,617
Segment Assets	172,785	162,207
Total Assets - United States	65,425	58,850
Total Assets - International	124,656	121,302
Total Assets	194,736	184,769
Upstream [Member]
Segment Assets
United States	32,648	26,319
International	91,016	89,306
Goodwill	4,655	4,617
Segment Assets	128,319	120,242
Downstream [Member]
Segment Assets
United States	21,974	21,406
International	22,492	20,559
Segment Assets	44,466	41,965
All Other [Member]
Segment Assets
United States	10,803	11,125
International	11,148	11,437
Total All Other	$ 21,951	$ 22,562

Operating Segments and Geographic Data (Details 2) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2011

Mar. 31, 2010

Sales and Other Operating Revenues

Total Sales and Other Operating Revenues

^[1]

$ 58,412

$ 46,741

Upstream [Member]

Sales and Other Operating Revenues

United States

6,666

6,593

International

12,869

9,548

Domestic and Intersegment Sales Revenue

19,535

16,141

Intersegment Elimination - United States

(4,265)

(3,473)

Intersegment Elimination - International

(8,453)

(5,705)

Total Segment Sales and Other Operating Revenues

6,817

6,963

Downstream [Member]

Sales and Other Operating Revenues

United States

21,434

17,718

International

30,057

21,967

Domestic and Intersegment Sales Revenue

51,491

39,685

Intersegment Elimination - United States

(20)

(28)

Intersegment Elimination - International

(20)

(22)

Total Segment Sales and Other Operating Revenues

51,451

39,635

All Other [Member]

Sales and Other Operating Revenues

United States

365

294

International

Domestic and Intersegment Sales Revenue

375

309

Intersegment Elimination - United States

(222)

(159)

Intersegment Elimination - International

(9)

(7)

Total Segment Sales and Other Operating Revenues

144

143

Sales and Other Operating Revenue [Member]

Sales and Other Operating Revenues

United States

28,465

24,605

International

42,936

31,530

Intersegment Elimination - United States

(4,507)

(3,660)

Intersegment Elimination - International

(8,482)

(5,734)

Total Segment Sales and Other Operating Revenues

$ 71,401

$ 56,135

[1]	Includes excise, value-added and similar taxes.

Employee Benefit Plans (Details) - USD ($) $ in Millions	3 Months Ended
Employee Benefit Plans (Details) - USD ($) $ in Millions	Mar. 31, 2011	Mar. 31, 2010
Pension Plans, Defined Benefit [Member]
Net Periodic Benefit Cost
Total net periodic benefit cost	$ 338	$ 284
U.S. [Member]
Net Periodic Benefit Cost
Service cost	94	84
Interest cost	116	122
Expected return on plan assets	(153)	(135)
Amortization of prior-service costs (credits)	(2)	(2)
Amortization of actuarial losses	77	80
Settlement losses	91	55
Total net periodic benefit cost	223	204
International [Member]
Net Periodic Benefit Cost
Service cost	45	36
Interest cost	82	73
Expected return on plan assets	(71)	(58)
Amortization of prior-service costs (credits)	6	5
Amortization of actuarial losses	26	24
Curtailment losses	27
Total net periodic benefit cost	115	80
Other Benefits [Member]
Net Periodic Benefit Cost
Service cost	14	10
Interest cost	45	43
Amortization of prior-service costs (credits)	(18)	(18)
Amortization of actuarial losses	16	6
Total net periodic benefit cost	$ 57	$ 41

Employee Benefit Plans (Details Textuals) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2011	Mar. 31, 2010
Additionals Employee Benefits (Textuals) [Abstract]
Maximum annual increase percentage to company contribution for retiree medical coverage	4.00%
Estimated contributions to employee pension plans	$ 950
Employee Benefits (Textuals) [Abstract]
Estimated contributions to employee pension plans at the end of the prior year	950
Estimated contributions to U.S. employee pension plans at the end of the prior year	650
Estimated contributions to international employee pension plans at the end of the prior year	300
Contributions to employee pension plans	171	$ 306
Contributions to other postretirement benefit plans	49
U.S. [Member]
Additionals Employee Benefits (Textuals) [Abstract]
Contributions to U.S. employee pension plans	117
Other Benefits [Member]
Additionals Employee Benefits (Textuals) [Abstract]
Estimated contributions to employee pension plans	$ 176

Litigation (Details) $ in Millions	1 Months Ended
Litigation (Details) $ in Millions	Sep. 30, 2010 USD ($)	Aug. 31, 2010	Mar. 31, 2011 USD ($)	Feb. 14, 2011 USD ($)	Nov. 30, 2008 USD ($)
Litigation (Textuals) [Abstract]
Pending lawsuits and claims			20
Remediation program			$ 40
Financial compensation for purported damages on mining engineer's report					$ 18,900
Assessment for purported unjust enrichment on mining engineer's report					$ 8,400
Court order requiring the parties to provide their positions on damages within (in days)		45 days
Approximate damages on plaintiffs' submission, Maximum	$ 76,000
Approximate damages on plaintiffs' submission, Minimum	16,000
Approximate unjust enrichment on plaintiffs' submission, Maximum	38,000
Approximate unjust enrichment on plaintiffs' submission, Minimum	$ 5,000
Amount assessed in damages				$ 8,600
Amount assessed for plaintiffs representatives				900
Additional amount assessed in punitive damages				$ 8,600

Fair Value Measurements (Details) - USD ($) $ in Millions	3 Months Ended
Fair Value Measurements (Details) - USD ($) $ in Millions	Mar. 31, 2011	Dec. 31, 2010	Mar. 31, 2010	Dec. 31, 2009
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Marketable securities	$ 145	$ 155
Derivatives	117	122
Total Assets at Fair Value	262	277
Fair Value, Liabilities Measured on Recurring Basis, Financial Statement Captions [Line Items]
Derivatives	286	171
Total Liabilities at Fair Value	286	171
Fair Value Measurements (Textuals) [Abstract]
Loss (before tax) properties, plant and equipment, net (held for sale)	10
Fair value of long-lived assets measured on a nonrecurring basis	0		$ 0
Carrying amount of investments written down to fair values	2
Fair value of investments	0
Before tax losses	2
Fair value of cash equivalents	$ 13,149	14,060	7,376	$ 8,716
Maturity period of primarily bank time deposits, classified as cash equivalents	90 days or less
Maturity period of bank time deposits	Greater than 90 days
Fair value of investments not included in cash and cash equivalents	$ 721	855
Carrying and fair value of time deposits	3,600	2,900
Carrying Amount of Long-term Debt [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying amount of long-term debt	5,600		5,600
Fair Value of Long-term Debt [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying amount of long-term debt	6,100		$ 6,300
Level 1 [Member]
Fair Value, Liabilities Measured on Recurring Basis, Financial Statement Captions [Line Items]
Derivatives	256	75
Total Liabilities at Fair Value	256	75
Level 2 [Member]
Fair Value, Liabilities Measured on Recurring Basis, Financial Statement Captions [Line Items]
Derivatives	30	96
Total Liabilities at Fair Value	30	96
Level 3 [Member]
Fair Value, Liabilities Measured on Recurring Basis, Financial Statement Captions [Line Items]
Derivatives	0	0
Total Liabilities at Fair Value	0	0
Level 1 [Member]
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Marketable securities	145	155
Derivatives	6	11
Total Assets at Fair Value	151	166
Level 2 [Member]
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Marketable securities	0	0
Derivatives	111	111
Total Assets at Fair Value	111	111
Level 3 [Member]
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Marketable securities	0	0
Derivatives	0	0
Total Assets at Fair Value	$ 0	$ 0

Fair Value Measurements (Details 1) - USD ($) $ in Millions	Mar. 31, 2011	Mar. 31, 2010
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement Captions [Line Items]
Properties, plant and equipment, net (held and used)	$ 0	$ 0
Properties, plant and equipment, net (held for sale)	3
Investments and advances	0
Total Assets at Fair Value	3
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement Captions [Line Items]
Properties, plant and equipment, net (held and used)	0
Properties, plant and equipment, net (held for sale)	0
Investments and advances	0
Total Assets at Fair Value	0
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement Captions [Line Items]
Properties, plant and equipment, net (held and used)	0
Properties, plant and equipment, net (held for sale)	3
Investments and advances	0
Total Assets at Fair Value	3
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement Captions [Line Items]
Properties, plant and equipment, net (held and used)	0
Properties, plant and equipment, net (held for sale)	0
Investments and advances	0
Total Assets at Fair Value	0
Before-Tax Loss [Member]
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement Captions [Line Items]
Properties, plant and equipment, net (held and used)	0
Properties, plant and equipment, net (held for sale)	10
Investments and advances	2
Total Assets at Fair Value	$ 12

Derivative Instruments and Hedging Activities (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2011	Mar. 31, 2010	Dec. 31, 2010
Consolidated Statement of Income: The Effect of Derivatives not Designated as Hedging Instruments
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ (397)	$ (25)
Consolidated Balance Sheet: Fair Value of Derivatives not Designated as Hedging Instruments
Total Assets at Fair Value	117		$ 122
Total Liabilities at Fair Value	286		$ 171
Purchased crude oil and products [Member] \| Commodity [Member]
Consolidated Statement of Income: The Effect of Derivatives not Designated as Hedging Instruments
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	4	(31)
Sales and other operating revenues [Member] \| Commodity [Member]
Consolidated Statement of Income: The Effect of Derivatives not Designated as Hedging Instruments
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(399)	$ 6
Other Income [Member] \| Commodity [Member]
Consolidated Statement of Income: The Effect of Derivatives not Designated as Hedging Instruments
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ (2)

Restructuring And Reorganization Costs (Details) $ in Millions	3 Months Ended
	Mar. 31, 2011 USD ($)	Mar. 31, 2010 USD ($)
Restructuring and reorganization
Balance at December 31, 2010	$ 138
Payments	(40)
Balance at March 31, 2011	$ 98
Restructuring and Reorganization (Textuals) [Abstract]
Employees in downstream expected to be terminated		3,200
Number of affected employees located in country		1,500
Number of employees terminated	1,900
Before-tax charges of restructuring and reorganization costs recorded in the first quarter of 2010		$ 244
Remaining accruals restructuring reserves	$ 138
Payments	$ 40

Acquisition of Atlas Energy, Inc. (Details) $ in Millions	Feb. 17, 2011 USD ($)
Preliminary allocation of the purchase price to Atlas's assets and liabilities
Current assets	$ 150
Investments and long-term receivables	456
Properties	6,051
Goodwill	39
Other assets	5
Total assets acquired	6,701
Current liabilities	(560)
Long-term debt and capital leases	(761)
Deferred income taxes	1,918
Other liabilities	(25)
Total liabilities assumed	(3,264)
Net assets acquired	$ 3,437

Acquisition of Atlas Energy Inc. (Details 1) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2011	Feb. 17, 2011
Acquisition Of Atlas Energy Inc (Textuals) [Abstract]
Purchase price of Atlas		$ 4,500
Assigned goodwill to the US within the upstream segment		39
Maximum period for adjustments to provisional fair value measurements	up to one year
Discount rate on future commodity prices	8.00%
Fair value of consideration transferred		3,400
Business Acquisition, Purchase Price Allocation, Goodwill, Expected Tax Deductible Amount		0
Atlas Energy Inc [Member]
Acquisition Of Atlas Energy Inc (Textuals) [Abstract]
Cash purchase of equity interest	$ 3,000	3,000
Advance to Atlas Energy	403
Assumed Debt of Atlas		$ 1,100
Payment to cash out Atlas equity awards	184
Laurel Mountain Midstream LLC [Member]
Acquisition Of Atlas Energy Inc (Textuals) [Abstract]
Advance to Atlas Energy	$ 403
Purchase of Interest in Laurel Mountain Midstream	49.00%	49.00%
Upstream Segment
Acquisition Of Atlas Energy Inc (Textuals) [Abstract]
Assigned goodwill to the US within the upstream segment		$ 39

Label	Element	Value
Long term receivables, net [Member] \| Commodity [Member]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	us-gaap_DerivativeInstrumentsNotDesignatedAsHedgingInstrumentsAssetAtFairValue	$ 64,000,000
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	us-gaap_DerivativeInstrumentsNotDesignatedAsHedgingInstrumentsAssetAtFairValue	61,000,000
Accounts and notes receivable, net [Member] \| Commodity [Member]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	us-gaap_DerivativeInstrumentsNotDesignatedAsHedgingInstrumentsAssetAtFairValue	58,000,000
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	us-gaap_DerivativeInstrumentsNotDesignatedAsHedgingInstrumentsAssetAtFairValue	56,000,000
Deferred credits and other noncurrent obligations [Member] \| Commodity [Member]
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	us-gaap_DerivativeInstrumentsNotDesignatedAsHedgingInstrumentsLiabilityAtFairValue	40,000,000
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	us-gaap_DerivativeInstrumentsNotDesignatedAsHedgingInstrumentsLiabilityAtFairValue	35,000,000
Accounts payable [Member] \| Commodity [Member]
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	us-gaap_DerivativeInstrumentsNotDesignatedAsHedgingInstrumentsLiabilityAtFairValue	131,000,000
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	us-gaap_DerivativeInstrumentsNotDesignatedAsHedgingInstrumentsLiabilityAtFairValue	$ 251,000,000

Interim Financial Statements (Details)	May 04, 2011
Interim Financial Statements (Details) [Abstract]
Net leasehold acreage to be acquired	228,000

Summarized Financial Data - Chevron U.S.A. Inc. (Details 1) - USD ($) $ in Millions	Mar. 31, 2011	Dec. 31, 2010	Mar. 31, 2010	Dec. 31, 2009
Balance Sheet - Chevron U.S.A. Inc.
Current assets	$ 50,851	$ 48,841
Current liabilities	33,313	29,012
Total CUSA net equity	110,850	105,811	$ 96,052	$ 92,561
Chevron U.S.A. Inc. [Member]
Balance Sheet - Chevron U.S.A. Inc.
Current assets	29,379	29,211
Other assets	41,903	35,294
Current liabilities	17,099	18,098
Other liabilities	22,928	16,785
Total CUSA net equity	31,255	29,622
Memo: Total debt	$ 12,665	$ 8,284

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
Income Taxes (Details) - USD ($) $ in Millions	Mar. 31, 2011	Mar. 31, 2010
Income Taxes (Textuals) [Abstract]
Income Tax Expense	$ 4,883	$ 3,070
Effective Tax Rates	44.00%	40.00%
Period for developments on tax matters in certain tax jurisdictions that may result in significant increases or decreases in the company's total unrecognized tax benefits (in months)	P12M

Other Contingencies and Commitments (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2011	Mar. 31, 2010	Dec. 31, 2009
Other Contingencies and Commitments (Textuals)
Indemnifications Equilon Motiva max future payments	$ 0	$ 300
Indemnifications Equilon Motiva YTD payments made	48
Indemnifications Unocal Environ Liabilities Max Obligation			$ 200
Equity Redetermination Naval Petro Reserve Max BT Liability	$ 200

Assets Held For Sale (Details) $ in Millions	Mar. 31, 2011 USD ($)
Assets Held For Sale (Textuals) [Abstract]
Net properties, plant and equipment classified as assets held for sale	$ 878

Consolidated Balance Sheet (Unaudited) (Parenthetical) - $ / shares	Mar. 31, 2011	Dec. 31, 2010
LIABILITIES AND EQUITY
Preferred stock, par value	$ 1	$ 1
Preferred stock, shares authorized	100,000,000	100,000,000
Preferred stock, shares issued	0	0
Common stock, par value	$ 0.75	$ 0.75
Common stock, shares authorized	6,000,000,000	6,000,000,000
Common stock, shares issued	2,442,676,580	2,442,676,580
Treasury stock, shares	432,406,439	435,195,799

Summarized Financial Data - Chevron Transport Corporation Ltd. (Details 1) - USD ($) $ in Millions	Mar. 31, 2011	Dec. 31, 2010	Mar. 31, 2010	Dec. 31, 2009
Balance Sheet - Chevron Transport Corporation
Current assets	$ 50,851	$ 48,841
Current liabilities	33,313	29,012
Total CTC net equity	110,850	105,811	$ 96,052	$ 92,561
Chevron Transport Corporation [Member]
Balance Sheet - Chevron Transport Corporation
Current assets	149	209
Other assets	230	201
Current liabilities	109	101
Other liabilities	70	75
Total CTC net equity	$ 200	$ 234