UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

þ	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended June 30, 2008
or
o	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission file number 1-368-2

Chevron Corporation

(Exact name of registrant as specified in its charter)

Delaware	94-0890210
(State or other jurisdiction of	(I.R.S. Employer
incorporation or organization)	Identification Number)
6001 Bollinger Canyon Road,	94583-2324
San Ramon, California	(Zip Code)
(Address of principal executive offices)

Registrant’s telephone number, including area code: (925) 842-1000

NONE
(Former name or former address, if changed since last report.)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.  Yes þ     No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer þ Accelerated filer o Non-accelerated filer o Smaller reporting company o

(Do not check if a smaller

reporting company)

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  Yes o     No þ

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date:

Class	Outstanding as of June 30, 2008
Common stock, $.75 par value	2,054,471,415

INDEX

		Page No.
	Cautionary Statements Relevant to Forward-Looking Information for the Purpose of “Safe Harbor” Provisions of the Private Securities Litigation Reform Act of 1995		2
PART I FINANCIAL INFORMATION
Item 1.	Consolidated Financial Statements —
	Consolidated Statement of Income for the Three and Six Months Ended June 30, 2008, and 2007		3
	Consolidated Statement of Comprehensive Income for the Three and Six Months Ended June 30, 2008, and 2007		4
	Consolidated Balance Sheet at June 30, 2008, and December 31, 2007		5
	Consolidated Statement of Cash Flows for the Six Months Ended June 30, 2008, and 2007		6
	Notes to Consolidated Financial Statements		7-20
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		21-36
Item 3.	Quantitative and Qualitative Disclosures about Market Risk		36
Item 4.	Controls and Procedures		36
PART II OTHER INFORMATION
Item 1.	Legal Proceedings		36
Item 1A.	Risk Factors		36
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		37
Item 4.	Submission of Matters to a Vote of Security Holders		37-38
Item 6.	Exhibits		38
Signature			39
Exhibits:	Computation of Ratio of Earnings to Fixed Charges		41
Rule 13a-14(a)/15d-14(a) Certifications			42-43
Section 1350 Certifications			44-45

1

CAUTIONARY STATEMENT RELEVANT TO FORWARD-LOOKING INFORMATION
FOR THE PURPOSE OF “SAFE HARBOR” PROVISIONS OF THE
PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995

This quarterly report on Form 10-Q of Chevron Corporation contains forward-looking statements relating to Chevron’s operations that are based on management’s current expectations, estimates, and projections about the petroleum, chemicals, and other energy-related industries. Words such as “anticipates,” “expects,” “intends,” “plans,” “targets,” “projects,” “believes,” “seeks,” “schedules,” “estimates,” “budgets” and similar expressions are intended to identify such forward-looking statements. These statements are not guarantees of future performance and are subject to certain risks, uncertainties and other factors, some of which are beyond our control and are difficult to predict. Therefore, actual outcomes and results may differ materially from what is expressed or forecasted in such forward-looking statements. The reader should not place undue reliance on these forward-looking statements, which speak only as of the date of this report. Unless legally required, Chevron undertakes no obligation to update publicly any forward-looking statements, whether as a result of new information, future events or otherwise.

Among the important factors that could cause actual results to differ materially from those in the forward-looking statements are crude-oil and natural-gas prices; refining, marketing and chemicals margins; actions of competitors; timing of exploration expenses; the competitiveness of alternate energy sources or product substitutes; technological developments; the results of operations and financial condition of equity affiliates; the inability or failure of the company’s joint-venture partners to fund their share of operations and development activities; the potential failure to achieve expected net production from existing and future crude-oil and natural-gas development projects; potential delays in the development, construction or start-up of planned projects; the potential disruption or interruption of the company’s net production or manufacturing facilities or delivery/transportation networks due to war, accidents, political events, civil unrest, severe weather or crude-oil production quotas that might be imposed by OPEC (Organization of Petroleum Exporting Countries); the potential liability for remedial actions or assessments under existing or future environmental regulations and litigation; significant investment or product changes under existing or future environmental statutes, regulations and litigation; the potential liability resulting from pending or future litigation; the company’s acquisition or disposition of assets; gains and losses from asset dispositions or impairments; government-mandated sales, divestitures, recapitalizations, industry-specific taxes, changes in fiscal terms or restrictions on scope of company operations; foreign currency movements compared with the U.S. dollar; the effects of changed accounting rules under generally accepted accounting principles promulgated by rule-setting bodies; and the factors set forth under the heading “Risk Factors” on pages 32 and 33 of the company’s 2007 Annual Report on Form 10-K/A. In addition, such statements could be affected by general domestic and international economic and political conditions. Unpredictable or unknown factors not discussed in this report could also have material adverse effects on forward-looking statements.

2

PART I.

FINANCIAL INFORMATION

Item 1.   Consolidated Financial Statements

CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF INCOME

(Unaudited)

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
	(Millions of dollars, except per-share amounts)
Revenues and Other Income
Sales and other operating revenues*	$	80,962	$	54,344	$	145,621	$	100,646
Income from equity affiliates		1,563		894		2,807		1,831
Other income		464		856		507		1,844
Total Revenues and Other Income		82,989		56,094		148,935		104,321
Costs and Other Deductions
Purchased crude oil and products		56,056		33,138		98,584		61,265
Operating expenses		5,248		4,124		9,703		7,737
Selling, general and administrative expenses		1,639		1,516		2,986		2,647
Exploration expenses		307		273		560		579
Depreciation, depletion and amortization		2,275		2,156		4,490		4,119
Taxes other than on income*		5,699		5,743		11,142		11,168
Interest and debt expense		—		63		—		137
Minority interests		34		19		62		47
Total Costs and Other Deductions		71,258		47,032		127,527		87,699
Income Before Income Tax Expense		11,731		9,062		21,408		16,622
Income Tax Expense		5,756		3,682		10,265		6,527
Net Income	$	5,975	$	5,380	$	11,143	$	10,095
Per Share of Common Stock:
Net Income
— Basic	$	2.91	$	2.52	$	5.41	$	4.72
— Diluted	$	2.90	$	2.52	$	5.38	$	4.70
Dividends	$	0.65	$	0.58	$	1.23	$	1.10
Weighted Average Number of Shares Outstanding (000s)
— Basic		2,050,773		2,127,763		2,058,596		2,136,591
— Diluted		2,064,888		2,141,583		2,072,549		2,149,686
* Includes excise, value-added and similar taxes:	$	2,652	$	2,609	$	5,189	$	5,023

See accompanying notes to consolidated financial statements.

3

CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended						Six Months Ended
	June 30						June 30
	2008			2007			2008			2007
	(Millions of dollars)
Net Income	$	5,975		$	5,380		$	11,143		$	10,095
Currency translation adjustment		(14	)		7			(17	)		3
Unrealized holding gain on securities:
Net gain arising during period		7			6			8			17
Derivatives:
Net derivatives loss on hedge transactions		—			(17	)		—			(10	)
Reclassification to net income of net realized gain		(45	)		(14	)		(41	)		(1	)
Income taxes on derivatives transactions		14			5			12			—
Total		(31	)		(26	)		(29	)		(11	)
Defined benefit plans:
Actuarial loss:
Amortization to net income of net actuarial loss		61			92			125			185
Actuarial gain arising during period		—			2			—			2
Prior service cost:
Amortization to net income of net prior service credits		(15	)		(2	)		(31	)		(6	)
Defined benefit plans sponsored by equity affiliates		7			8			15			8
Income taxes on defined benefit plans		(19	)		(31	)		(48	)		(67	)
Total		34			69			61			122
Other Comprehensive Gain (Loss), Net of Tax		(4	)		56			23			131
Comprehensive Income	$	5,971		$	5,436		$	11,166		$	10,226

See accompanying notes to consolidated financial statements.

4

CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEET

(Unaudited)

	At June 30			At December 31
	2008			2007
	(Millions of dollars, except
	per-share amounts)
ASSETS
Cash and cash equivalents	$	8,180		$	7,362
Marketable securities		427			732
Accounts and notes receivable, net		30,591			22,446
Inventories:
Crude oil and petroleum products		4,876			4,003
Chemicals		355			290
Materials, supplies and other		1,140			1,017
Total inventories		6,371			5,310
Prepaid expenses and other current assets		4,140			3,527
Total Current Assets		49,709			39,377
Long-term receivables, net		2,261			2,194
Investments and advances		20,793			20,477
Properties, plant and equipment, at cost		161,451			154,084
Less: accumulated depreciation, depletion and amortization		79,057			75,474
Properties, plant and equipment, net		82,394			78,610
Deferred charges and other assets		3,280			3,491
Goodwill		4,629			4,637
Total Assets	$	163,066		$	148,786
LIABILITIES AND STOCKHOLDERS’ EQUITY
Short-term debt	$	894		$	1,162
Accounts payable		29,240			21,756
Accrued liabilities		5,196			5,275
Federal and other taxes on income		5,656			3,972
Other taxes payable		1,501			1,633
Total Current Liabilities		42,487			33,798
Long-term debt		5,382			5,664
Capital lease obligations		388			406
Deferred credits and other noncurrent obligations		15,580			15,007
Noncurrent deferred income taxes		12,259			12,170
Reserves for employee benefit plans		4,476			4,449
Minority interests		226			204
Total Liabilities		80,798			71,698
Preferred stock (authorized 100,000,000 shares, $1.00 par value, none issued)		—			—
Common stock (authorized 6,000,000,000 shares, $.75 par value, 2,442,676,580 shares issued at June 30, 2008, and December 31, 2007)		1,832			1,832
Capital in excess of par value		14,378			14,289
Retained earnings		90,937			82,329
Notes receivable — key employees		(1	)		(1	)
Accumulated other comprehensive loss		(1,992	)		(2,015	)
Deferred compensation and benefit plan trust		(433	)		(454	)
Treasury stock, at cost (388,205,165 and 352,242,618 shares at June 30, 2008, and December 31, 2007, respectively)		(22,453	)		(18,892	)
Total Stockholders’ Equity		82,268			77,088
Total Liabilities and Stockholders’ Equity	$	163,066		$	148,786

See accompanying notes to consolidated financial statements.

5

CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF CASH FLOWS

(Unaudited)

	Six Months Ended
	June 30
	2008			2007
	(Millions of dollars)
Operating Activities
Net income	$	11,143		$	10,095
Adjustments
Depreciation, depletion and amortization		4,490			4,118
Dry hole expense		199			244
Distributions greater (less) than income from equity affiliates		105			(507	)
Net before-tax gains on asset retirements and sales		(123	)		(1,756	)
Net foreign currency effects		30			252
Deferred income tax provision		(381	)		(227	)
Net increase in operating working capital		(502	)		(488	)
Minority interest in net income		62			47
Increase in long-term receivables		(167	)		(46	)
Increase in other deferred charges		(7	)		(56	)
Cash contributions to employee pension plans		(127	)		(179	)
Other		589			692
Net Cash Provided by Operating Activities		15,311			12,189
Investing Activities
Capital expenditures		(8,971	)		(6,957	)
Proceeds from asset sales		418			2,412
Net sales of marketable securities		297			37
Repayment of loans by equity affiliates		162			10
Proceeds from sale of other short-term investments		261			—
Net Cash Used for Investing Activities		(7,833	)		(4,498	)
Financing Activities
Net borrowings (payments) of short-term obligations		308			(872	)
Repayments of long-term debt and other financing obligations		(877	)		(1,192	)
Cash dividends		(2,538	)		(2,352	)
Dividends paid to minority interests		(41	)		(48	)
Net purchases of treasury shares		(3,561	)		(2,579	)
Net Cash Used for Financing Activities		(6,709	)		(7,043	)
Effect of Exchange Rate Changes on Cash and Cash Equivalents		49			75
Net Change in Cash and Cash Equivalents		818			723
Cash and Cash Equivalents at January 1		7,362			10,493
Cash and Cash Equivalents at June 30	$	8,180		$	11,216

See accompanying notes to consolidated financial statements.

6

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Note 1.   Interim Financial Statements

The accompanying consolidated financial statements of Chevron Corporation and its subsidiaries (the company) have not been audited by independent accountants. In the opinion of the company’s management, the interim data include all adjustments necessary for a fair statement of the results for the interim periods. These adjustments were of a normal recurring nature.

Certain notes and other information have been condensed or omitted from the interim financial statements presented in this Quarterly Report on Form 10-Q. Therefore, these financial statements should be read in conjunction with the company’s 2007 Annual Report on Form 10-K/A.

The results for the three- and six-month periods ended June 30, 2008, are not necessarily indicative of future financial results.

Earnings in the first quarter 2007 included a $700 million gain on a sale of the company’s interest in refining and related assets in the Netherlands. Second quarter 2007 results included a $680 million gain on the sale of the company’s holding of Dynegy Inc. common stock.

Note 2.   Information Relating to the Statement of Cash Flows

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

	Six Months Ended
	June 30
	2008			2007
	(Millions of dollars)
Increase in accounts and notes receivable	$	(8,160	)	$	(1,464	)
Increase in inventories		(1,062	)		(590	)
Increase in prepaid expenses and other current assets		(216	)		(484	)
Increase in accounts payable and accrued liabilities		7,438			1,014
Increase in income and other taxes payable		1,498			1,036
Net decrease in operating working capital	$	(502	)	$	(488	)

In accordance with the cash-flow classification requirements of FAS 123R, Share-Based Payment, the “Net increase in operating working capital” includes reductions of $98 million and $65 million for excess income tax benefits associated with stock options exercised during the six months ended June 30, 2008 and 2007, respectively. These amounts are offset by an equal amount in “Net purchases of treasury shares.”

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

	Six Months Ended
	June 30
	2008		2007
	(Millions of dollars)
Interest on debt (net of capitalized interest)	$	2	$	149
Income taxes		8,679		5,696

7

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

	Six Months Ended
	June 30
	2008			2007
	(Millions of dollars)
Marketable securities purchased	$	(3,103	)	$	(836	)
Marketable securities sold		3,400			873
Net sales of marketable securities	$	297		$	37

The “Net purchases of treasury shares” represents the cost of common shares acquired in the open market less the cost of shares issued for share-based compensation plans. Net purchases totaled $3.6 billion and $2.6 billion in the 2008 and 2007 periods, respectively. Purchases in the first half of 2008 were under the company’s stock repurchase program initiated in September 2007.

The major components of “Capital expenditures” and the reconciliation of this amount to the capital and exploratory expenditures, including equity affiliates, presented in “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” are presented in the following table:

	Six Months Ended
	June 30
	2008			2007
	(Millions of dollars)
Additions to properties, plant and equipment	$	8,433		$	6,365
Additions to investments		487			464
Current-year dry-hole expenditures		154			209
Payments for other liabilities and assets, net		(103	)		(81	)
Capital expenditures		8,971			6,957
Expensed exploration expenditures		361			335
Assets acquired through capital lease obligations		11			183
Capital and exploratory expenditures, excluding equity affiliates		9,343			7,475
Company’s share of expenditures by equity affiliates		941			1,096
Capital and exploratory expenditures, including equity affiliates	$	10,284		$	8,571

Note 3.   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. For this purpose, the investments are grouped as follows: upstream — exploration and production; downstream — refining, marketing and transportation; chemicals; and all other. The first three of these groupings represent the company’s “reportable segments” and “operating segments” as defined in Financial Accounting Standards Board (FASB) Statement No. 131, Disclosures about Segments of an Enterprise and Related Information (FAS 131).

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 FAS 131). The CODM is the company’s Executive Committee, a committee of senior officers that includes the Chief Executive Officer, and that in turn reports to the Board of Directors of Chevron Corporation.

The operating segments represent components of the company as described in FAS 131 terms 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 to assess their performance; and (c) for which discrete financial information is available.

8

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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 Executive Committee also have individual management responsibilities and participate in other committees for purposes other than acting as the CODM.

“All other” activities include mining operations, power generation businesses, worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities, alternative fuels, technology companies, and the company’s interest in Dynegy Inc. prior to its sale in May 2007.

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.” Income by major operating area for the three- and six-month periods ended June 30, 2008 and 2007, is presented in the following table:

Segment Income

	Three Months Ended						Six Months Ended
	June 30						June 30
	2008			2007			2008			2007
	(Millions of dollars)
Upstream
United States	$	2,191		$	1,223		$	3,790		$	2,019
International		5,057			2,416			8,586			4,527
Total Upstream		7,248			3,639			12,376			6,546
Downstream
United States		(682	)		781			(678	)		1,131
International		(52	)		517			196			1,790
Total Downstream		(734	)		1,298			(482	)		2,921
Chemicals
United States		1			60			2			139
International		40			44			82			85
Total Chemicals		41			104			84			224
Total Segment Income		6,555			5,041			11,978			9,691
All Other
Interest Expense		—			(40	)		—			(88	)
Interest Income		48			115			105			213
Other		(628	)		264			(940	)		279
Net Income	$	5,975		$	5,380		$	11,143		$	10,095

9

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Segment Assets  Segment assets do not include intercompany investments or intercompany receivables. “All Other” assets in 2008 consist primarily of worldwide cash, cash equivalents and marketable securities, real estate, information systems, mining operations, power generation businesses, technology companies and assets of the corporate administrative functions. Segment assets at June 30, 2008, and December 31, 2007, are as follows:

Segment Assets

	At June 30		At December 31
	2008		2007
	(Millions of dollars)
Upstream
United States	$	25,831	$	23,535
International		65,130		61,049
Goodwill		4,629		4,637
Total Upstream		95,590		89,221
Downstream
United States		19,230		16,790
International		31,049		26,075
Total Downstream		50,279		42,865
Chemicals
United States		2,567		2,484
International		981		870
Total Chemicals		3,548		3,354
Total Segment Assets		149,417		135,440
All Other
United States		5,573		6,847
International		8,076		6,499
Total All Other		13,649		13,346
Total Assets — United States		53,201		49,656
Total Assets — International		105,236		94,493
Goodwill		4,629		4,637
Total Assets	$	163,066	$	148,786

Segment Sales and Other Operating Revenues  Operating-segment sales and other operating revenues, including internal transfers, for the three- and six-month periods ended June 30, 2008 and 2007, 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 transportation and trading of crude oil and refined products. Revenues for the chemicals segment are derived primarily from the manufacture and sale of additives for lubricants and fuels. “All Other” activities include revenues from mining operations of coal and other minerals, power generation businesses, insurance operations, real estate activities and technology companies.

10

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Sales and Other Operating Revenues

	Three Months Ended						Six Months Ended
	June 30						June 30
	2008			2007			2008			2007
	(Millions of dollars)
Upstream
United States	$	12,111		$	8,073		$	21,944		$	15,095
International		13,780			8,719			24,219			16,097
Sub-total		25,891			16,792			46,163			31,192
Intersegment Elimination — United States		(4,782	)		(2,700	)		(8,633	)		(4,987	)
Intersegment Elimination — International		(8,399	)		(5,073	)		(14,169	)		(8,915	)
Total Upstream		12,710			9,019			23,361			17,290
Downstream
United States		27,957			19,247			50,111			34,950
International		39,793			25,597			71,162			47,544
Sub-total		67,750			44,844			121,273			82,494
Intersegment Elimination — United States		(135	)		(133	)		(251	)		(267	)
Intersegment Elimination — International		(44	)		(9	)		(63	)		(15	)
Total Downstream		67,571			44,702			120,959			82,212
Chemicals
United States		146			172			278			323
International		429			346			822			657
Sub-total		575			518			1,100			980
Intersegment Elimination — United States		(71	)		(66	)		(129	)		(118	)
Intersegment Elimination — International		(40	)		(38	)		(79	)		(80	)
Total Chemicals		464			414			892			782
All Other
United States		439			372			764			643
International		19			21			37			38
Sub-total		458			393			801			681
Intersegment Elimination — United States		(235	)		(179	)		(381	)		(310	)
Intersegment Elimination — International		(6	)		(5	)		(11	)		(9	)
Total All Other		217			209			409			362
Sales and Other Operating Revenues
United States		40,653			27,864			73,097			51,011
International		54,021			34,683			96,240			64,336
Sub-total		94,674			62,547			169,337			115,347
Intersegment Elimination — United States		(5,223	)		(3,078	)		(9,394	)		(5,682	)
Intersegment Elimination — International		(8,489	)		(5,125	)		(14,322	)		(9,019	)
Total Sales and Other Operating Revenues	$	80,962		$	54,344		$	145,621		$	100,646

11

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Note 4.   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 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 (CPChem) joint venture, which is accounted for using the equity method.

The summarized financial information for CUSA and its consolidated subsidiaries is presented in the table below.

	Six Months Ended
	June 30
	2008		2007
	(Millions of dollars)
Sales and other operating revenues	$	109,290	$	71,500
Costs and other deductions		106,379		67,691
Net income		1,796		3,553

	At June 30		At December 31
	2008		2007
	(Millions of dollars)
Current assets	$	39,928	$	32,803
Other assets		29,481		27,401
Current liabilities		26,571		20,050
Other liabilities		12,311		11,447
Net equity	$	30,527	$	28,707
Memo: Total debt	$	4,333	$	4,433

Note 5.   Summarized Financial Data — Chevron Transport Corporation

Chevron Transport Corporation Limited (CTC), incorporated in Bermuda, is an indirect, wholly owned subsidiary of Chevron Corporation. CTC is the principal operator of Chevron’s international tanker fleet and is engaged in the marine transportation of crude oil and refined petroleum products. Most of CTC’s shipping revenue is derived by providing transportation services to other Chevron companies. Chevron Corporation has fully and unconditionally guaranteed this subsidiary’s obligations in connection with certain debt securities issued by a third party. Summarized financial information for CTC and its consolidated subsidiaries is presented as follows:

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
	(Millions of dollars)
Sales and other operating revenues	$	260	$	182	$	501	$	339
Costs and other deductions		234		177		453		331
Net income		27		5		90		11

12

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

	At June 30		At December 31
	2008		2007
	(Millions of dollars)
Current assets	$	472	$	335
Other assets		176		337
Current liabilities		116		107
Other liabilities		87		188
Net equity	$	445	$	377

There were no restrictions on CTC’s ability to pay dividends or make loans or advances at June 30, 2008.

Note 6.   Income Taxes

Taxes on income for the second quarter and first half of 2008 were $5.8 billion and $10.3 billion, respectively, compared with $3.7 billion and $6.5 billion for the corresponding periods in 2007. The associated effective tax rates for the second quarters of 2008 and 2007 were 49 percent and 41 percent, respectively. For the comparative six-month periods, the effective tax rates were 48 percent and 39 percent, respectively. The 2008 rates in the comparative periods were higher primarily because a greater proportion of income was earned in international upstream tax jurisdictions, which generally have higher income tax rates than other tax jurisdictions. The 2007 second quarter included a relatively low effective tax rate on the sale of the company’s investment in Dynegy common stock. In addition, the 2007 six-month period included a relatively low effective tax rate on the first quarter sale of refining-related assets in the Netherlands.

Note 7.   Employee Benefits

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 pre-funding provides economic advantages. In the United States, this includes all qualified plans subject to the Employee Retirement Income Security Act of 1974 (ERISA) minimum funding standard. The company does not typically fund U.S. nonqualified pension plans that are not subject to funding requirements under applicable 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 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.

13

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

The components of net periodic benefit costs for 2008 and 2007 were:

	Three Months Ended						Six Months Ended
	June 30						June 30
	2008			2007			2008			2007
	(Millions of dollars)
Pension Benefits
United States
Service cost	$	62		$	65		$	125		$	130
Interest cost		124			121			249			242
Expected return on plan assets		(148	)		(145	)		(296	)		(289	)
Amortization of prior-service costs		(2	)		11			(4	)		23
Amortization of actuarial losses		15			32			30			64
Settlement losses		20			21			39			41
Total United States		71			105			143			211
International
Service cost		35			32			68			62
Interest cost		70			66			143			127
Expected return on plan assets		(63	)		(67	)		(133	)		(130	)
Amortization of prior-service costs		7			4			13			8
Amortization of actuarial losses		17			20			37			40
Curtailment losses		—			3			—			3
Termination costs		1			—			1			—
Total International		67			58			129			110
Net Periodic Pension Benefit Costs	$	138		$	163		$	272		$	321
Other Benefits*
Service cost	$	49		$	24		$	56		$	32
Interest cost		45			47			89			92
Amortization of prior-service costs		(20	)		(20	)		(40	)		(40	)
Amortization of actuarial losses		9			19			19			40
Net Periodic Other Benefit Costs	$	83		$	70		$	124		$	124

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

At the end of 2007, the company estimated it would contribute $500 million to employee pension plans during 2008 (composed of $300 million for the U.S. plans and $200 million for the international plans). Through June 30, 2008, a total of $127 million was contributed (including $61 million to the U.S. plans). Total estimated contributions for the full year continue to be $500 million, but the company may contribute an amount that differs from this estimate. Actual contribution amounts are dependent upon investment returns, changes in pension obligations, regulatory environments and other economic factors. Additional funding may ultimately be required if investment returns are insufficient to offset increases in plan obligations.

During the first half of 2008, the company contributed $96 million to its other postretirement benefit plans. The company anticipates contributing $112 million during the remainder of 2008.

14

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Note 8.   Accounting for Suspended Exploratory Wells

The company accounts for the cost of exploratory wells in accordance with FAS 19, Financial Accounting and Reporting by Oil and Gas Producing Companies, as amended by FASB Staff Position FAS 19-1, Accounting for Suspended Well Costs, which provides that an exploratory well continues to be capitalized after the completion of drilling if certain criteria are met. The company’s capitalized cost of suspended wells at June 30, 2008, was $1.84 billion, an increase of approximately $180 million from year-end 2007 due primarily to activities in the United States, Nigeria and Australia. For the category of exploratory well costs at year-end 2007 that were suspended more than one year, a total of $65 million was expensed in the first half of 2008.

Note 9.   Litigation

MTBE  Chevron and many other companies in the petroleum industry have used methyl tertiary butyl ether (MTBE) as a gasoline additive. The company is a party to 89 lawsuits and claims, the majority of which involve numerous other petroleum marketers and refiners, related to the use of MTBE in certain oxygenated gasolines and the alleged seepage of MTBE into groundwater. Chevron has agreed in principle to a tentative settlement of 59 pending lawsuits and claims. The terms of this agreement which is currently under court review are confidential and not material to the company’s results of operations, liquidity or financial position.

Resolution of remaining 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 tentative settlement of the referenced 59 lawsuits did not set any precedents related to standards of liability to be used to judge the merits of the claims, corrective measures required or monetary damages to be assessed for the remaining lawsuits and claims or future lawsuits and claims. As a result, the company’s ultimate exposure related to pending lawsuits and claims is not currently 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.

RFG Patent  Fourteen purported class actions were brought by consumers of reformulated gasoline (RFG) alleging that Unocal misled the California Air Resources Board into adopting standards for composition of RFG that overlapped with Unocal’s undisclosed and pending patents. Eleven lawsuits were consolidated in U.S. District Court for the Central District of California, where a class action has been certified, and three were consolidated in a state court action. Unocal is alleged to have monopolized, conspired and engaged in unfair methods of competition, resulting in injury to consumers of RFG. Plaintiffs in both consolidated actions seek unspecified actual and punitive damages, attorneys’ fees, and interest on behalf of an alleged class of consumers who purchased “summertime” RFG in California from January 1995 through August 2005. The parties have reached a tentative agreement to resolve all of the above matters in an amount that is not material to the company’s results of operations, liquidity or financial position. The terms of this agreement are confidential, and subject to further negotiation and approval, including by the courts.

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

15

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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 to Chevron; 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. 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 April 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 $8 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, healthcare systems, and additional infrastructure for Petroecuador. The engineer’s report also asserts that an additional $8.3 billion could be assessed against Chevron for unjust enrichment. The engineer’s report is not binding on the court. Chevron also believes that the engineer’s work was performed, and his report prepared, in a manner contrary to law and in violation of the court’s orders. Chevron intends to move to strike the report and otherwise continue a vigorous defense against any attempted imposition of liability.

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 engineer’s report, management does not believe the report itself 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).

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 contractual obligations relating 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, storage and regasification 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 June 2008, the company 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

16

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

arisen prior to December 2001. Claims must be asserted no later than February 2009 for Equilon indemnities and 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 has not recorded any liabilities for possible claims under these indemnities. The company posts no assets as collateral and has made no payments under the indemnities.

The amounts payable for the indemnities described above 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. Under the indemnification agreement, the company’s liability is unlimited until April 2022, when the liability expires. The acquirer of the assets sold in 1997 shares in certain environmental remediation costs up to a maximum obligation of $200 million, which had not been reached as of June 30, 2008.

Minority Interests  The company has commitments of $226 million related to minority interests in subsidiary companies.

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.

Chevron’s environmental reserve at December 31, 2007, was approximately $1.5 billion. At June 30, 2008, the environmental reserve increased to approximately $1.9 billion. The increase was mainly associated with remediation liabilities Chevron has incurred for sites that were previously sold.

Financial Instruments  The company believes it has no material market or credit risks to its operations, financial position or liquidity as a result of its commodities and other derivatives activities, including forward-exchange contracts and interest rate swaps.

Equity Redetermination  For oil and 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. A wide range remains for a possible net settlement amount for the four zones. For this range of settlement, Chevron estimates its maximum possible net before-tax liability at approximately $200 million, and the possible maximum net amount that could be owed to Chevron is estimated at about $150 million. The timing of the settlement and the exact amount within this range of estimates are uncertain.

17

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Other Contingencies  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.

Note 11.   Restructuring and Reorganization Costs

In 2007, the company implemented a restructuring and reorganization program in its global downstream operations. Approximately 1,000 employees were eligible for severance payments. As of June 30, 2008, approximately 600 employees had been terminated under the program. Most of the associated positions are located outside of the United States. The program is expected to be complete by the end of 2009.

Shown in the table below is the activity for the company’s liability related to the downstream reorganization. The associated charges against income were categorized as “Operating expenses” or “Selling, general and administrative expenses” on the Consolidated Statement of Income.

	Amounts Before Tax
	(Millions of dollars)
Balance at January 1, 2008	$	85
Accruals/Adjustments		—
Payments		(36	)
Balance at June 30, 2008	$	49

Note 12.   Fair Value Measurements

The company implemented FASB Statement No. 157, Fair Value Measurements (FAS 157), as of January 1, 2008. FAS 157 was amended in February 2008 by FASB Staff Position (FSP) FAS No. 157-1, Application of FASB Statement No. 157 to FASB Statement No. 13 and Its Related Interpretive Accounting Pronouncements That Address Leasing Transactions, and by FSP FAS 157-2, Effective Date of FASB Statement No. 157, which delayed the company’s application of FAS 157 for nonrecurring nonfinancial assets and liabilities until January 1, 2009.

Implementation of FAS 157 did not have a material effect on the company’s results of operations or consolidated financial position and had no effect on the company’s existing fair-value measurement practices. However, FAS 157 requires disclosure of a 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.

18

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Level 3: Unobservable inputs. The company does not use Level 3 inputs for any of its recurring fair-value measurements. Beginning January 1, 2009, Level 3 inputs may be required for the determination of fair value associated with certain nonrecurring measurements of nonfinancial assets and liabilities.

The fair value hierarchy for assets and liabilities measured at fair value at June 30, 2008, is as follows:

Assets and Liabilities Measured at Fair Value on a Recurring Basis

			Prices in Active		Other
			Markets for		Observable		Unobservable
	At June 30		Identical Assets		Inputs		Inputs
	2008		(Level 1)		(Level 2)		(Level 3)
Marketable Securities	$	427	$	427	$	—	$	—
Derivatives		326		107		219		—
Total Assets at Fair Value	$	753	$	534	$	219	$	—
Derivatives	$	1,105	$	171	$	934	$	—
Total Liabilities at Fair Value	$	1,105	$	171	$	934	$	—

Marketable securities  The company calculates fair value for its marketable securities based on quoted market prices for identical assets and liabilities.

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, as well as interest-rate swaps and foreign-currency forward contracts. Derivatives classified as Level 1 include futures, swaps and options contracts traded in active markets such as the NYMEX (New York Mercantile Exchange). Level 2 derivatives include swaps (including interest rate), options, and forward (including foreign currency) contracts principally with financial institutions and other oil and gas companies, the fair values for which are obtained from third party broker quotes, industry pricing services and exchanges. These Level 2 fair values are routinely corroborated on a sample basis with observable market-based inputs.

Note 13.   New Accounting Standards

FASB Statement No. 141 (revised 2007), Business Combinations (FAS 141-R)  In December 2007, the FASB issued FAS 141-R, which will become effective for business combination transactions having an acquisition date on or after January 1, 2009. This standard requires the acquiring entity in a business combination to recognize the assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree at the acquisition date to be measured at their respective fair values. The Statement requires acquisition-related costs, as well as restructuring costs the acquirer expects to incur for which it is not obligated at acquisition date, to be recorded against income rather than included in purchase-price determination. It also requires recognition of contingent arrangements at their acquisition-date fair values, with subsequent changes in fair value generally reflected in income.

FASB Statement No. 160, Noncontrolling Interests in Consolidated Financial Statements, an amendment of ARB No. 51 (FAS 160)  The FASB issued FAS 160 in December 2007, which will become effective for the company January 1, 2009, with retroactive adoption of the Statement’s presentation and disclosure requirements for existing minority interests. This standard will require ownership interests in subsidiaries held by parties other than the parent to be presented within the equity section of the consolidated statement of financial position but separate from the parent’s equity. It will also require the amount of consolidated net income attributable to the parent and the

19

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

noncontrolling interest to be clearly identified and presented on the face of the consolidated income statement. Certain changes in a parent’s ownership interest are to be accounted for as equity transactions and when a subsidiary is deconsolidated, any noncontrolling equity investment in the former subsidiary is to be initially measured at fair value. The company does not anticipate the implementation of FAS 160 will significantly change the presentation of its consolidated income statement or consolidated balance sheet.

FASB Statement No. 161, Disclosures about Derivative Instruments and Hedging Activities (FAS 161)  In March 2008, the FASB issued FAS 161, which becomes effective for the company on January 1, 2009. This standard amends and expands the disclosure requirements of FASB Statement No. 133, Accounting for Derivative Instruments and Hedging Activities. FAS 161 requires disclosures related to objectives and strategies for using derivatives; the fair-value amounts of, and gains and losses on, derivative instruments; and credit-risk-related contingent features in derivative agreements. The effect on the company’s disclosures for derivative instruments as a result of the adoption of FAS 161 in 2009 will depend on the company’s derivative instruments and hedging activities at that time.

20

Item 2.   Management’s Discussion and Analysis of Financial Condition and Results of Operations

Second Quarter 2008 Compared with Second Quarter 2007
and Six Months 2008 Compared with Six Months 2007

Key Financial Results

Income by Business Segment

	Three Months Ended						Six Months Ended
	June 30						June 30
	2008			2007			2008			2007
				(Millions of dollars)
Upstream — Exploration and Production
United States	$	2,191		$	1,223		$	3,790		$	2,019
International		5,057			2,416			8,586			4,527
Total Upstream		7,248			3,639			12,376			6,546
Downstream — Refining, Marketing and Transportation
United States		(682	)		781			(678	)		1,131
International		(52	)		517			196			1,790
Total Downstream		(734	)		1,298			(482	)		2,921
Chemicals		41			104			84			224
Total Segment Income		6,555			5,041			11,978			9,691
All Other		(580	)		339			(835	)		404
Net Income*	$	5,975		$	5,380		$	11,143		$	10,095
* Includes foreign currency effects	$	126		$	(138	)	$	81		$	(258	)

Net income for the second quarter 2008 was $6.0 billion ($2.90 per share — diluted), compared with $5.4 billion ($2.52 per share — diluted) in the corresponding 2007 period. Net income for the first six months of 2008 was $11.1 billion ($5.38 per share — diluted), vs. $10.1 billion ($4.70 per share — diluted) in the 2007 first half. In the following discussion, the term “earnings” is defined as segment income.

Upstream earnings in the second quarter of 2008 were $7.2 billion, compared with $3.6 billion in the year-ago period. Earnings for the first half of 2008 were $12.4 billion, vs. $6.5 billion a year earlier. The increase between both comparative periods was driven by higher prices for crude oil and natural gas.

Downstream incurred a loss of $734 million in the second quarter of 2008, compared with earnings of $1.3 billion a year earlier. For the six-month periods, a loss of $482 million was recorded in 2008 versus earnings of $2.9 billion in 2007. The 2007 first half included an approximate $700 million gain on the first-quarter sale of the company’s interest in a refinery and related assets in the Netherlands. The losses in the 2008 periods were associated mainly with market conditions that prevented the higher price of crude-oil feedstocks used in the refining process from being fully recovered in the sales price of gasoline and other refined products.

Chemicals earned $41 million and $84 million for the second quarter and first-half 2008, respectively. Comparative amounts in 2007 were $104 million and $224 million.

Refer to pages 25 to 27 for additional discussion of earnings by business segment and “All Other” activities for the second quarter and first six months of 2008 versus the same periods in 2007.

Business Environment and Outlook

Chevron is a global energy company with its most significant business activities in the following countries: Angola, Argentina, Australia, Azerbaijan, Bangladesh, Brazil, Cambodia, Canada, Chad, China, Colombia,

21

Democratic Republic of the Congo, Denmark, France, India, Indonesia, Kazakhstan, Myanmar, the Netherlands, Nigeria, Norway, the Partitioned Neutral Zone between Kuwait and Saudi Arabia, the Philippines, Qatar, Republic of the Congo, Singapore, South Africa, South Korea, Thailand, Trinidad and Tobago, the United Kingdom, the United States, Venezuela and Vietnam.

Chevron’s current and future earnings depend largely on the profitability of its upstream (exploration and production) and downstream (refining, marketing and transportation) business segments. The single biggest factor that affects the results of operations for both segments is movement in the price of crude oil. In the downstream business, crude oil is the largest cost component of refined products. The overall trend in earnings is typically less affected by results from the company’s chemicals business and other activities and investments. Earnings for the company in any period may also be influenced by events or transactions that are infrequent and/or unusual in nature.

Chevron and the oil and gas industry at large continue to experience an increase in certain costs that exceeds the general trend of inflation in many areas of the world. This increase in costs is affecting the company’s operating expenses for all business segments and capital expenditures, but particularly for the upstream business. The company’s operations, particularly upstream, can also be affected by changing economic, regulatory and political environments in the various countries in which it operates, including the United States. Civil unrest, acts of violence or strained relations between a government and the company or other governments may impact the company’s operations or investments. Those developments have at times significantly affected the company’s related operations and results and are carefully considered by management when evaluating the level of current and future activity in such countries.

To sustain its long-term competitive position in the upstream business, the company must develop and replenish an inventory of projects that offer adequate financial returns for the investment required. Identifying promising areas for exploration, acquiring the necessary rights to explore for and to produce crude oil and natural gas, drilling successfully, and handling the many technical and operational details in a safe and cost-effective manner, are all important factors in this effort. Projects often require long lead times and large capital commitments. In the current environment of higher commodity prices, certain governments have sought to renegotiate contracts or impose additional costs and taxes on the company. Other governments may attempt to do so in the future. The company will continue to monitor these developments, take them into account in evaluating future investment opportunities, and otherwise seek to mitigate any risks to the company’s current operations or future prospects.

The company also continually evaluates opportunities to dispose of assets that are not key to providing sufficient long-term value, or to acquire assets or operations complementary to its asset base to help augment the company’s growth. Asset dispositions and restructurings may occur in future periods and could result in significant gains or losses.

Comments related to earnings trends for the company’s major business areas are as follows:

Upstream  Earnings for the upstream segment are closely aligned with industry price levels for crude oil and natural gas. Crude-oil and natural-gas prices are subject to external factors over which the company has no control, including product demand connected with global economic conditions, industry inventory levels, production quotas imposed by the Organization of Petroleum Exporting Countries (OPEC), weather-related damage and disruptions, competing fuel prices, and regional supply interruptions or fears thereof that may be caused by military conflicts, civil unrest or political uncertainty. Moreover, any of these factors could also inhibit the company’s production capacity in an affected region. The company monitors developments closely in the countries in which it operates and holds investments, and attempts to manage risks in operating its facilities and business.

Price levels for capital and exploratory costs and operating expenses associated with the efficient production of crude-oil and natural-gas can also be subject to external factors beyond the company’s control. External factors include not only the general level of inflation but also prices charged by the industry’s material- and service-providers, which can be affected by the volatility of the industry’s own supply and demand conditions for such materials and services. The oil and gas industry worldwide has experienced significant price increases for these items since 2005, and future price increases may continue to exceed the general level of inflation. Capital and exploratory expenditures and operating expenses also can be affected by damages to production facilities caused by severe weather or civil unrest.

22

During 2007, industry price levels for West Texas Intermediate (WTI), a benchmark crude oil, averaged $72 per barrel. The price for WTI averaged $111 per barrel for the first half of 2008 and was about $124 per barrel at the end of July. Worldwide crude oil prices have remained strong due mainly to increasing demand in growing economies, the heightened level of geopolitical uncertainty in some areas of the world and supply concerns in other key producing regions.

As in 2007, a wide differential in prices existed during the first half of 2008 between high-quality (high-gravity, low sulfur) crude oils and those of lower quality (low-gravity, high sulfur). The relatively lower price for the heavier crudes has been associated with an ample supply and a relatively lower demand due to the limited number of refineries that are able to process this lower-quality feedstock into light products (motor gasoline, jet fuel, aviation gasoline and diesel fuel). The price for higher-quality crude oil has remained high, as the demand for light products, which can be more easily manufactured by refineries from high-quality crude oil, has been strong worldwide. Chevron produces or shares in the production of heavy crude oil in California, Chad, Indonesia, the Partitioned Neutral Zone between Saudi Arabia and Kuwait, Venezuela and in certain fields in Angola, China and the United Kingdom North Sea. (Refer to page 30 for the company’s average U.S. and international crude-oil realizations.)

In contrast to price movements in the global market for crude oil, price changes for natural gas in many regional markets are more closely aligned with supply and demand conditions in those markets. In the United States, benchmark prices at Henry Hub averaged nearly $10 per thousand cubic feet (MCF) in the first half of 2008, compared with $7.40 for the first half of 2007 and about $7 for the full year 2007. At the end of July 2008, the Henry Hub spot price was approximately $9 per MCF. Fluctuations in the price for natural gas in the United States are closely associated with the volumes produced in North America and the inventory in underground storage relative to customer demand.

Certain other regions of the world in which the company operates have different supply, demand and regulatory circumstances, typically resulting in significantly lower average sales prices for the company’s production of natural gas. (Refer to page 30 for the company’s average natural gas realizations for the U.S. and international regions.) Additionally, excess-supply conditions that exist in certain parts of the world cannot easily serve to mitigate the relatively high-price conditions in the United States and other markets because of the lack of infrastructure to transport and receive liquefied natural gas.

To help address this regional imbalance between supply and demand for natural gas, Chevron is planning increased investments in long-term projects in areas of excess supply to install infrastructure to produce and liquefy natural gas for transport by tanker, along with investments and commitments to regasify the product in markets where demand is strong and supplies are not as plentiful. Due to the significance of the overall investment in these long-term projects, the natural-gas sales prices in the areas of excess supply (before the natural gas is transferred to a company-owned or third-party processing facility) are expected to remain well below sales prices for natural gas that is produced much nearer to areas of high demand and can be transported in existing natural gas pipeline networks (as in the United States).

Besides the impact of the fluctuation in prices for crude oil and natural gas, the longer-term trend in earnings for the upstream segment is also a function of other factors, including the company’s ability to find or acquire and efficiently produce crude oil and natural gas, changes in fiscal terms of contracts, changes in tax rates on income, and the cost of goods and services.

In the first half of 2008, the company’s worldwide oil-equivalent production averaged approximately 2.57 million barrels per day. At the beginning of 2008, the company estimated production for the full year at 2.65 million barrels per day under a set of crude-oil and natural-gas price assumptions for the year. Actual crude-oil prices in the 2008 first half were higher than the prices used in the production forecast, and the impact of these higher prices reduced the anticipated volumes recoverable under certain production-sharing and variable-royalty agreements outside the United States. This difference in recovered volumes accounted for most of the variation between the first half of 2008 actual reported rate of production and the full-year forecast. The full-year production outlook is also subject to other factors and many uncertainties, including quotas that may be imposed by OPEC, changes in fiscal terms or restrictions on the scope of company operations, delays in project start-ups, and production disruptions that could be caused by severe weather, local civil unrest and changing geopolitics. Future

23

production levels also are affected by the size and number of economic investment opportunities and, for new large-scale projects, the time lag between initial exploration and the beginning of production. A significant majority of Chevron’s upstream investment is currently being made outside the United States. Investments in upstream projects generally begin well in advance of the start of the associated crude-oil and natural-gas production. For example, the company’s recently announced startup of the 68 percent-owned deepwater Agbami project in Nigeria was associated with a 1998 crude-oil discovery. The total maximum oil-equivalent production at Agbami is estimated at 250,000 barrels per day by the end of 2009.

About one-fourth of the company’s net oil-equivalent production in the first half of 2008 occurred in the OPEC-member countries of Angola, Indonesia, Nigeria and Venezuela and in the Partitioned Neutral Zone between Saudi Arabia and Kuwait. OPEC quotas did not significantly affect Chevron’s production level in 2007 or in the first half of 2008. The impact of quotas on the company’s production in future periods is uncertain.

Refer to the Results of Operations on pages 25 through 26 for additional discussion of the company’s upstream business.

Downstream  Earnings for the downstream segment are closely tied to margins on the refining and marketing of products that include gasoline, diesel, jet fuel, lubricants, fuel oil and feedstocks for chemical manufacturing. Industry margins are sometimes volatile and can be affected by the global and regional supply-and-demand balance for refined products and by changes in the price of crude oil used for refinery feedstock. Industry margins can also be influenced by refined-product inventory levels, geopolitical events, refinery maintenance programs and disruptions at refineries resulting from unplanned outages that may be due to severe weather, fires or other operational events.

Other factors affecting profitability for downstream operations include the reliability and efficiency of the company’s refining and marketing network, the effectiveness of the crude-oil and product-supply functions and the economic returns on invested capital. Profitability can also be affected by the volatility of tanker-charter rates for the company’s shipping operations, which are driven by the industry’s demand for crude-oil and product tankers. Other factors beyond the company’s control include the general level of inflation and energy costs to operate the company’s refinery and distribution network.

The company’s most significant marketing areas are the West Coast of North America, the U.S. Gulf Coast, Latin America, Asia, sub-Saharan Africa and the United Kingdom. Chevron operates or has ownership interests in refineries in each of these areas, except Latin America. Downstream earnings, especially in the United States, have been weak since mid-2007 due mainly to increasing prices of crude oil used in the refining process that have not always been fully recovered through sales prices of refined products.

Refer to the Results of Operations on pages 26 through 27 for additional discussion of the company’s downstream operations.

Chemicals  Earnings in the petrochemicals business are closely tied to global chemical demand, industry inventory levels and plant capacity utilization. Feedstock and fuel costs, which tend to follow crude-oil and natural-gas price movements, also influence earnings in this segment.

Refer to the Results of Operations on page 27 for additional discussion of chemical earnings.

Results of Operations

Business Segments  The following section presents the results of operations for the company’s business segments — upstream, downstream and chemicals — as well as for “all other” — the departments and companies managed at the corporate level. (Refer to Note 3 beginning on page 8 for a discussion of the company’s “reportable segments,” as defined in FAS 131, Disclosures about Segments of an Enterprise and Related Information.)

24

Upstream

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
			(Millions of dollars)
U.S. Upstream Income	$	2,191	$	1,223	$	3,790	$	2,019

U.S. upstream income of $2.2 billion in the second quarter of 2008 increased nearly $1 billion from the same period last year. Higher prices for crude oil and natural gas benefited earnings by about $1.6 billion between periods. Partially offsetting this benefit were an increase in operating expenses, the impact of lower production and the absence of gains on asset sales.

Six-month 2008 earnings were $3.8 billion, compared with $2 billion a year earlier. Higher prices for crude oil and natural gas increased earnings by about $2.7 billion between periods. Partially offsetting this benefit were the same factors as mentioned above for the fluctuation in earnings between the quarterly periods.

The average realization for crude oil and natural gas liquids in the second quarter of 2008 was $109 per barrel, compared with $57 a year earlier. Six-month prices were $98 and $54 for 2008 and 2007, respectively. The average natural-gas realization was $9.84 per thousand cubic feet in the 2008 quarter, compared with $6.56 in the year-ago period. First-half realizations were $8.67 in 2008 and $6.48 in 2007.

Net oil-equivalent production was 702,000 barrels per day in the second quarter 2008, down 50,000 barrels per day from the corresponding period in 2007. First-half production was 708,000 barrels per day, down 42,000 barrels per day from the first six months of 2007. The lower production in 2008 for both comparative periods was associated with normal field declines. The net liquids component of oil-equivalent production decreased by 6 percent for both the quarter and first half, to 438,000 barrels per day and 437,000, respectively. Net natural gas production averaged 1.6 billion cubic feet per day for both the second quarter and six months of 2008, down about 7 percent and 5 percent, respectively, from the comparative 2007 periods.

	Three Months Ended					Six Months Ended
	June 30					June 30
	2008		2007			2008			2007
			(Millions of dollars)
International Upstream Income*	$	5,057	$	2,416		$	8,586		$	4,527
* Includes foreign currency effects	$	80	$	(111	)	$	(87	)	$	(230	)

International upstream income of $5.1 billion in the second quarter of 2008 increased $2.6 billion from a year earlier. Higher prices for crude oil and natural gas benefited earnings about $2.7 billion between periods. Partially offsetting the benefit of higher prices was a reduction of crude-oil sales volumes. Foreign currency effects benefited earnings by $80 million in the 2008 quarter, compared with a $111 million reduction to income a year earlier.

For the six-month period, earnings were $8.6 billion, up about $4.1 billion from the 2007 period. Higher prices for crude oil and natural gas in 2008 increased earnings by about $4.6 billion. Partially offsetting the benefit of higher prices was a reduction of crude-oil sales volumes, as well as higher operating and depreciation expenses. Foreign currency effects reduced income by $87 million in 2008, compared with a $230 million reduction to earnings a year earlier.

The average realization for crude oil and natural gas liquids the second quarter 2008 was about $110 per barrel, versus $61 in the 2007 period. For the first half of 2008, the average realization was $99 per barrel, compared with $56 for the six months of 2007. The average natural-gas realization in the 2008 second quarter was $5.44 per thousand cubic feet, up from $3.64 in the second quarter last year. Between the six-month periods, the average natural gas realization increased to $5.13 from $3.74.

Net oil-equivalent production, including volumes from oil sands in Canada, was 1.84 million barrels per day in the second quarter 2008, down 43,000 barrels per day from the year-ago period. Production for the first half of 2008 was 1.86 million barrels per day, down 27,000 from the 2007 first half. Absent the impact of higher prices on certain production-sharing and variable-royalty agreements, net production increased between both comparative periods.

25

The net liquids component of oil-equivalent production was 1.23 million barrels per day and 1.24 million barrels per day for the second quarter and first half of 2008, respectively. Each was about 7 percent lower than the corresponding 2007 period. Net natural gas production of 3.62 billion cubic feet per day in the second quarter 2008 and 3.70 billion cubic feet per day in first half of 2008 increased 9 percent and 12 percent, respectively from the year-earlier periods.

Downstream

	Three Months Ended					Six Months Ended
	June 30					June 30
	2008			2007		2008			2007
	(Millions of dollars)
U.S. Downstream (Loss) Income	$	(682	)	$	781	$	(678	)	$	1,131

U.S. downstream incurred a loss of $682 million in the second quarter of 2008 and a loss of $678 million in the first half of the year. In 2007, income of $781 million and $1.1 billion was recorded in the second quarter and first-half periods. The losses for both periods in 2008 were associated with higher costs of crude-oil feedstocks used in the refining process that were not fully recovered in the sales price of gasoline and other refined products. The losses in both periods also included mark-to-market accounting effects of commodity derivative instruments.

Crude-oil inputs to the company’s refineries were 816,000 barrels per day in the second quarter of 2008, down about 7 percent from a year earlier. The decline was primarily due to the effects of a planned turnaround at the company’s refinery in Pascagoula, Mississippi, and suspension of crude processing for asphalt production at the refinery in Perth Amboy, New Jersey. Crude-oil inputs of 855,000 barrels per day in the first half of 2008 increased about 6 percent from the 2007 six-month period as a result of less downtime for refinery turnarounds.

Refined-product sales volumes of 1.38 million barrels per day in the 2008 second quarter were down 8 percent from the corresponding 2007 quarter due primarily to reduced sales of gasoline and gas oils. Branded gasoline sales of 596,000 barrels per day were 5 percent lower. For the six months of 2008, refined-product sales volumes of 1.41 million barrels per day were 5 percent lower than the 2007 first half due to reduced demand for gasoline.

	Three Months Ended						Six Months Ended
	June 30						June 30
	2008			2007			2008		2007
	(Millions of dollars)
International Downstream (Loss) Income*	$	(52	)	$	517		$	196	$	1,790
* Includes foreign currency effects	$	46		$	(35	)	$	157	$	(30	)

International downstream incurred a loss of $52 million in the second quarter of 2008, compared with income of $517 million in the corresponding 2007 period. Earnings for the six months of 2008 were $196 million, down nearly $1.6 billion from the 2007 first-half, which included a $700 million gain recorded in the first quarter on the sale of the company’s interest in a refinery and related assets in the Netherlands. The decline in earnings otherwise between the comparative periods was primarily associated with higher costs of crude-oil feedstocks used in the refining process that were not fully recovered in the sales price of gasoline and other refined products. The decline in earnings for both comparative periods also included the mark-to-market accounting effects of commodity derivative instruments. Foreign currency effects increased 2008 income for the second quarter and first half of 2008 by $46 million and $157 million, respectively. In 2007, foreign currency effects reduced earnings $35 million and $30 million in the comparative periods.

The company’s share of refinery crude-oil inputs were 952,000 barrels per day in the second quarter of 2008, up about 1 percent from the year-ago period. Increased volumes at the GS Caltex affiliate’s refinery in South Korea and the company’s refinery in Cape Town, South Africa, were partially offset due to unplanned shutdowns at the company’s Pembroke refinery in the United Kingdom. For the six-month period, crude-oil inputs were 960,000 barrels per day, down 5 percent due to the sale of the company’s interest in a Netherlands refinery.

26

Total refined-product sales volumes of 2.07 million barrels per day in the 2008 quarter were 6 percent higher than last year’s corresponding period. Excluding the impact of the 2007 asset sales in Europe, sales volumes were up 8 percent between periods on increased trading activity. Between the six-month periods, refined-product sales of 2.06 million barrels per day increased by about 2 percent.

Chemicals

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
	(Millions of dollars)
Income*	$	41	$	104	$	84	$	224
* Includes foreign currency effects	$	1	$	—	$	—	$	(1	)

Chemical operations earned $41 million in the second quarter 2008, compared with $104 million in the 2007 period. For the six months, earnings decreased from $224 million in 2007 to $84 million in 2008. Reduced earnings for both comparative periods were associated with lower margins on sales of lubricant and fuel additives by the company’s Oronite subsidiary and on sales of commodity chemicals by the 50 percent-owned Chevron Phillips Chemical Company LLC (CPChem). The reduced margins reflected higher costs of feedstocks that could not be fully recovered in product sales prices. Also contributing to the lower earnings between periods were higher utility costs associated with the manufacturing process and increased maintenance expenses for the planned shutdowns at various U.S. manufacturing facilities.

All Other

	Three Months Ended					Six Months Ended
	June 30					June 30
	2008			2007		2008			2007
	(Millions of dollars)
(Charges) Income — Net*	$	(580	)	$	339	$	(835	)	$	404
* Includes foreign currency effects	$	(1	)	$	8	$	11		$	3

All Other includes mining operations, power generation businesses, worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities, alternative fuels and technology companies, and the company’s interest in Dynegy prior to its sale in May 2007.

Net charges in the second quarter of 2008 were $580 million, compared with income of $339 million in the same quarter of 2007. For the six months of 2008, net charges were $835 million, compared with income of $404 million a year earlier. The 2007 periods included a gain of $680 million related to the sale of the company’s investment in Dynegy common stock, a loss of approximately $160 million associated with the early redemption of Texaco Capital Inc. bonds and net favorable tax items. Results in 2008 included net unfavorable corporate tax items and increased costs of environmental remediation for sites that previously had been closed or sold.

Consolidated Statement of Income

Explanations of variations between periods for certain income statement categories are provided below:

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
			(Millions of dollars)
Sales and other operating revenues	$	80,962	$	54,344	$	145,621	$	100,646

27

Sales and other operating revenues in the second quarter of 2008 increased $27 billion from a year earlier due to higher prices for crude oil, natural gas, natural gas liquids and refined products. Between the six-month periods, sales and other operating revenues increased $45 billion due to higher prices.

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
	(Millions of dollars)
Income from equity affiliates	$	1,563	$	894	$	2,807	$	1,831

Income from equity affiliates increased for the quarterly and six-month periods due mainly to higher upstream-related earnings from Tengizchevroil in Kazakhstan.

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
	(Millions of dollars)
Other income	$	464	$	856	$	507	$	1,844

Other income for the quarterly period in 2008 decreased due to the absence of a $680 million gain last year on the sale of the company’s investment in Dynegy. Also contributing to the decrease in the six-month period was the absence of a $780 million before-tax gain on the sale of the company’s 31 percent interest in a refinery and related assets in the Netherlands. These gains were partially offset by a $224 million before-tax loss on the redemption of debt in 2007.

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
			(Millions of dollars)
Purchased crude oil and products	$	56,056	$	33,138	$	98,584	$	61,265

Purchases increased $23 billion and $37 billion in the quarterly and six-month periods due to higher prices for crude oil, natural gas and refined products.

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
			(Millions of dollars)
Operating, selling, general and administrative expenses	$	6,887	$	5,640	$	12,689	$	10,384

Operating, selling, general and administrative expenses increased approximately $1.2 billion between the quarterly periods. The categories of expense with the largest increases were employee and contract labor — $384 million and environmental remediation — $187 million. Other categories of expense increased less than $150 million each.

Between the six-month periods, total expenses increased approximately $2.3 billion. The categories of expense with the largest increases were employee and contract labor — $699 million, environmental remediation — $327 million, and equipment rental — $219 million. Other categories of expense increased less than $200 million each.

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
	(Millions of dollars)
Exploration expenses	$	307	$	273	$	560	$	579

Exploration expenses in the 2008 second quarter increased due to higher amounts for well write-offs and geological and geophysical costs. The decrease in the six-month period related to lower amounts for well write-offs in the 2008 first quarter.

28

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
	(Millions of dollars)
Depreciation, depletion and amortization	$	2,275	$	2,156	$	4,490	$	4,119

The increase in both comparative periods was associated with higher depreciation rates for certain oil and gas producing fields, reflecting completion of higher-cost development projects and asset retirement obligations.

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
	(Millions of dollars)
Taxes other than on income	$	5,699	$	5,743	$	11,142	$	11,168

Taxes other than on income was relatively unchanged from the 2007 periods.

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
	(Millions of dollars)
Interest and debt expense	$	—	$	63	$	—	$	137

Interest and debt expense was zero in 2008 due to all interest-related amounts being capitalized.

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
	(Millions of dollars)
Income tax expense	$	5,756	$	3,682	$	10,265	$	6,527

Effective income tax rates for the 2008 and 2007 second quarters were 49 percent and 41 percent, respectively. For the year-to-date periods, the effective tax rates were 48 and 39 percent, respectively. The higher rates in 2008 were due to a greater proportion of income being earned in international upstream tax jurisdictions, which generally have higher income tax rates than other tax jurisdictions. The 2007 second quarter included a relatively low effective tax rate on the sale of the company’s investment in Dynegy common stock. In addition, the 2007 six-month period included a relatively low effective tax rate on the first-quarter sale of refining-related assets in the Netherlands.

29

Selected Operating Data

The following table presents a comparison of selected operating data:

Selected Operating Data(1)(2)

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
U.S. Upstream
Net crude-oil and natural-gas-liquids production (MBPD)		438		468		437		464
Net natural-gas production (MMCFPD)(3)		1,588		1,703		1,627		1,713
Net oil-equivalent production (MBOEPD)		702		752		708		750
Sales of natural gas (MMCFPD)		7,631		8,153		7,817		8,004
Sales of natural gas liquids (MBPD)		167		170		156		155
Revenue from net production
Crude oil and natural gas liquids ($/Bbl.)	$	108.67	$	57.27	$	97.66	$	53.64
Natural gas ($/MCF)	$	9.84	$	6.56	$	8.67	$	6.48
International Upstream
Net crude-oil and natural-gas-liquids production (MBPD)		1,207		1,297		1,218		1,307
Net natural-gas production (MMCFPD)(3)		3,621		3,314		3,695		3,293
Net oil-equivalent production (MBOEPD)(4)		1,835		1,878		1,860		1,887
Sales of natural gas (MMCFPD)		4,205		3,839		4,190		3,865
Sales of natural gas liquids (MBPD)(5)		127		123		131		116
Revenue from liftings
Crude oil and natural gas liquids ($/Bbl.)	$	110.44	$	61.32	$	98.63	$	56.33
Natural gas ($/MCF)	$	5.44	$	3.64	$	5.13	$	3.74
U.S. and International Upstream
Total net oil-equivalent production, including volumes from oil sands (MBOEPD)(3)(4)		2,537		2,630		2,568		2,637
U.S. Downstream
Gasoline sales (MBPD)(6)		677		741		687		735
Sales of other refined products(MBPD)		706		765		721		742
Total		1,383		1,506		1,408		1,477
Refinery input (MBPD)		816		881		855		805
International Downstream
Gasoline sales (MBPD)(6)		512		458		507		466
Sales of other refined products (MBPD)		1,043		1,034		1,048		1,074
Share of affiliate sales (MBPD)		511		464		504		469
Total		2,066		1,956		2,059		2,009
Refinery input (MBPD)		952		942		960		1,006
(1) Includes company share of equity affiliates.
(2) MBPD — thousands of barrels per day; MMCFPD — millions of cubic feet per day; Bbl. — Barrel; MCF — thousands of cubic feet; oil-equivalent gas (OEG) conversion ratio is 6,000 cubic feet of natural gas = 1 barrel of crude oil; MBOEPD — thousands of barrels of oil-equivalent per day.
(3) Includes natural gas consumed in operations (MMCFPD):
United States		69		52		80		60
International		424		411		454		420
(4) Includes production from oil sands — net (MBPD):		24		29		26		31
(5) 2007 conformed to 2008 presentation.
(6) Includes branded and unbranded gasoline.

30

Liquidity and Capital Resources

Cash and cash equivalents and marketable securities totaled $8.6 billion at June 30, 2008, up $500 million from year-end 2007. Cash provided by operating activities in the first half of 2008 was $15.3 billion, an amount sufficient to fund the company’s capital and exploratory program, dividend payments and repurchases of common stock.

Dividends  The company paid dividends of $2.5 billion to common stockholders during the first six months of 2008. In April 2008, the company increased its quarterly dividend by 12.1 percent to 65 cents per share.

Debt and Capital Lease and Minority Interest Obligations  Chevron’s total debt and capital lease obligations were $6.7 billion at June 30, 2008, down from $7.2 billion at December 31, 2007. The decline was associated with $750 million of Chevron Canada Funding Company bonds that matured in February 2008. The company also had minority interest obligations of $226 million at June 30, 2008.

The company’s debt and capital lease obligations due within one year, consisting primarily of commercial paper and the current portion of long-term debt, totaled $5.5 billion at June 30, 2008, and December 31, 2007. Of these amounts, $4.6 billion and $4.4 billion were reclassified to long-term at the end of each period, respectively. At June 30, 2008, settlement of these obligations was not expected to require the use of working capital within one year, as the company had the intent and the ability, as evidenced by committed credit facilities, to refinance them on a long-term basis.

At June 30, 2008, the company had $5 billion in committed credit facilities with various major banks, which permit the refinancing of short-term obligations on a long-term basis. These facilities support commercial paper borrowing and also can 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 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 June 30, 2008. In addition, the company has an automatic shelf registration statement that expires in March 2010 for an unspecified amount of non-convertible debt securities issued or guaranteed by the company.

The company has outstanding public bonds issued by Chevron Corporation Profit Sharing/Savings Plan Trust Fund, Texaco Capital Inc. and Union Oil Company of California. All of these securities are guaranteed by Chevron Corporation and are rated AA by Standard and Poor’s Corporation and Aa1 by Moody’s Investors Service. The company’s U.S. commercial paper is rated A-1+ by Standard and Poor’s and P-1 by Moody’s. All of these ratings denote high-quality, investment-grade securities.

The company’s future debt level is dependent primarily on results of operations, the capital-spending program and cash that may be generated from asset dispositions. The company believes that it has substantial borrowing capacity to meet unanticipated cash requirements and that during periods of low prices for crude oil and natural gas and narrow margins for refined products and commodity chemicals, it has the flexibility to increase borrowings and/or modify capital-spending plans to continue paying the common stock dividend and maintain the company’s high-quality debt ratings.

Common Stock Repurchase Program  In September 2007, the company authorized the acquisition of up to $15 billion of its common shares from time to time at prevailing prices, as permitted by securities laws and other legal requirements and subject to market conditions and other factors. The program is for a period of up to three years and may be discontinued at any time. The company acquired 20.5 million shares in the open market for $2.0 billion during the second quarter of 2008. From the inception of the program in September 2007 through July 2008, the company had purchased 70.2 million shares for approximately $6.4 billion.

Current Ratio — current assets divided by current liabilities. The current ratio was 1.2 at June 30, 2008, and at December 31, 2007. The current ratio is adversely affected by the valuation of Chevron’s inventories on a LIFO basis. At December 31, 2007, the book value of inventory was approximately $7 billion lower than replacement

31

costs, based on average acquisition costs during the year. The company does not consider its inventory valuation methodology to affect liquidity.

Debt Ratio — total debt as a percentage of total debt plus equity. This ratio was 7.5 percent at June 30, 2008, and 8.6 percent at year-end 2007, respectively.

Pension Obligations  At the end of 2007, the company estimated it would contribute $500 million to employee pension plans during 2008 (composed of $300 million for the U.S. plans and $200 million for the international plans). Through June 30, 2008, a total of $127 million was contributed (including $61 million to the U.S. plans). Total estimated contributions for the full year continue to be $500 million, but the company may contribute an amount that differs from this estimate. Actual contribution amounts are dependent upon investment returns, changes in pension obligations, regulatory environments and other economic factors. Additional funding may ultimately be required if investment returns are insufficient to offset increases in plan obligations.

Capital and Exploratory Expenditures  Total expenditures, including the company’s share of spending by affiliates, were $10.3 billion in the first six months of 2008, compared with $8.6 billion in the corresponding 2007 period. The amounts included the company’s share of equity-affiliate expenditures of $900 million and $1.1 billion in the 2008 and 2007 periods, respectively. Expenditures for upstream projects in 2008 were about $8.4 billion, representing 82 percent of the companywide total.

Capital and Exploratory Expenditures by Major Operating Area

	Three Months Ended				Six Months Ended
	June 30				June 30
	2008		2007		2008		2007
United States
Upstream	$	1,239	$	970	$	2,690	$	1,890
Downstream		528		325		900		558
Chemicals		21		38		127		67
All Other		142		133		265		396
Total United States		1,930		1,466		3,982		2,911
International
Upstream		2,887		2,579		5,723		4,826
Downstream		325		460		554		809
Chemicals		13		11		22		22
All Other		2		—		3		3
Total International		3,227		3,050		6,302		5,660
Worldwide	$	5,157	$	4,516	$	10,284	$	8,571

Contingencies and Significant Litigation

MTBE  Chevron and many other companies in the petroleum industry have used methyl tertiary butyl ether (MTBE) as a gasoline additive. The company is a party to 89 lawsuits and claims, the majority of which involve numerous other petroleum marketers and refiners, related to the use of MTBE in certain oxygenated gasolines and the alleged seepage of MTBE into groundwater. Chevron has agreed in principle to a tentative settlement of 59 pending lawsuits and claims. The terms of this agreement which is currently under court review are confidential and not material to the company’s results of operations, liquidity or financial position.

Resolution of remaining 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 tentative settlement of the referenced 59 lawsuits did not set any precedents related to standards of liability to be used to judge

32

the merits of the claims, corrective measures required or monetary damages to be assessed for the remaining lawsuits and claims or future lawsuits and claims. As a result, the company’s ultimate exposure related to pending lawsuits and claims is not currently 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.

RFG Patent  Fourteen purported class actions were brought by consumers of reformulated gasoline (RFG) alleging that Unocal misled the California Air Resources Board into adopting standards for composition of RFG that overlapped with Unocal’s undisclosed and pending patents. Eleven lawsuits were consolidated in U.S. District Court for the Central District of California, where a class action has been certified, and three were consolidated in a state court action. Unocal is alleged to have monopolized, conspired and engaged in unfair methods of competition, resulting in injury to consumers of RFG. Plaintiffs in both consolidated actions seek unspecified actual and punitive damages, attorneys’ fees, and interest on behalf of an alleged class of consumers who purchased “summertime” RFG in California from January 1995 through August 2005. The parties have reached a tentative agreement to resolve all of the above matters in an amount that is not material to the company’s results of operations, liquidity or financial position. The terms of this agreement are confidential, and subject to further negotiation and approval, including by the courts.

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 to Chevron; 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. 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 April 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 $8 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, healthcare systems, and additional infrastructure for Petroecuador. The engineer’s report also asserts that an additional $8.3 billion could be assessed against Chevron for unjust enrichment. The engineer’s report is not binding on the court. Chevron also believes that the engineer’s work was performed, and his report prepared, in a manner contrary to law and in violation of the court’s orders. Chevron intends to move to strike the report and otherwise continue a vigorous defense against any attempted imposition of liability.

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 engineer’s report, management does not believe the report itself has any utility in calculating a reasonably possible loss (or a range of loss). Moreover, the highly uncertain legal

33

environment surrounding the case provides no basis for management to estimate a reasonably possible loss (or a range of loss).

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 contractual obligations relating 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, storage and regasification 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 June 2008, the company 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 must be asserted no later than February 2009 for Equilon indemnities and 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 has not recorded any liabilities for possible claims under these indemnities. The company posts no assets as collateral and has made no payments under the indemnities.

The amounts payable for the indemnities described above 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. Under the indemnification agreement, the company’s liability is unlimited until April 2022, when the liability expires. The acquirer of the assets sold in 1997 shares in certain environmental remediation costs up to a maximum obligation of $200 million, which had not been reached as of June 30, 2008.

Minority Interests  The company has commitments of $226 million related to minority interests in subsidiary companies.

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.

34

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.

Chevron’s environmental reserve at December 31, 2007, was approximately $1.5 billion. At June 30, 2008, the environmental reserve increased to approximately $1.9 billion. The increase was mainly associated with remediation liabilities Chevron has incurred for sites that were previously sold.

Financial Instruments  The company believes it has no material market or credit risks to its operations, financial position or liquidity as a result of its commodities and other derivatives activities, including forward-exchange contracts and interest rate swaps.

Income Taxes  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 June 30, 2008. For Chevron’s major tax jurisdictions, the latest years for which income tax examinations had been finalized were as follows: United States — 2003, Nigeria — 1994, Angola — 2001 and Saudi Arabia — 2003.

Settlement of open tax years, as well as tax issues in other countries where the company conducts its businesses, is not expected to have a material effect on the consolidated financial position or liquidity of the company and, in the opinion of management, adequate provision has been made for income and franchise taxes for all years under examination or subject to future examination.

Equity Redetermination  For oil and 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. A wide range remains for a possible net settlement amount for the four zones. For this range of settlement, Chevron estimates its maximum possible net before-tax liability at approximately $200 million, and the possible maximum net amount that could be owed to Chevron is estimated at about $150 million. The timing of the settlement and the exact amount within this range of estimates are uncertain.

Other Contingencies  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.

New Accounting Standards

FASB Statement No. 141 (revised 2007), Business Combinations (FAS 141-R)  In December 2007, the FASB issued FAS 141-R, which will become effective for business combination transactions having an acquisition date on or after January 1, 2009. This standard requires the acquiring entity in a business combination to recognize the assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree at the acquisition date to be measured at their respective fair values. The Statement requires acquisition-related costs, as well as restructuring costs the acquirer expects to incur for which it is not obligated at acquisition date, to be recorded against income rather than included in purchase-price determination. It also requires recognition of contingent arrangements at their acquisition-date fair values, with subsequent changes in fair value generally reflected in income.

35

FASB Statement No. 160, Noncontrolling Interests in Consolidated Financial Statements, an amendment of ARB No. 51 (FAS 160)  The FASB issued FAS 160 in December 2007, which will become effective for the company January 1, 2009, with retroactive adoption of the Statement’s presentation and disclosure requirements for existing minority interests. This standard will require ownership interests in subsidiaries held by parties other than the parent to be presented within the equity section of the consolidated statement of financial position but separate from the parent’s equity. It will also require the amount of consolidated net income attributable to the parent and the noncontrolling interest to be clearly identified and presented on the face of the consolidated income statement. Certain changes in a parent’s ownership interest are to be accounted for as equity transactions and when a subsidiary is deconsolidated, any noncontrolling equity investment in the former subsidiary is to be initially measured at fair value. The company does not anticipate the implementation of FAS 160 will significantly change the presentation of its consolidated income statement or consolidated balance sheet.

FASB Statement No. 161, Disclosures about Derivative Instruments and Hedging Activities (FAS 161)  In March 2008, the FASB issued FAS 161, which becomes effective for the company on January 1, 2009. This standard amends and expands the disclosure requirements of FASB Statement No. 133, Accounting for Derivative Instruments and Hedging Activities. FAS 161 requires disclosures related to objectives and strategies for using derivatives; the fair-value amounts of, and gains and losses on, derivative instruments; and credit-risk-related contingent features in derivative agreements. The effect on the company’s disclosures for derivative instruments as a result of the adoption of FAS 161 in 2009 will depend on the company’s derivative instruments and hedging activities at that time.

Item 3.   Quantitative and Qualitative Disclosures About Market Risk

Information about market risks for the three months ended June 30, 2008, does not differ materially from that discussed under Item 7A of Chevron’s 2007 Annual Report on Form 10-K/A.

Item 4.   Controls and Procedures

(a) Evaluation of disclosure controls and procedures

Chevron management has evaluated, with the participation of the Chief Executive Officer and Chief Financial Officer, the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) as of the end of the period covered by this report. Based on this evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the company’s disclosure controls and procedures were effective as of June 30, 2008.

(b) Changes in internal control over financial reporting

During the quarter ended June 30, 2008, there were no changes in the company’s internal control over financial reporting that have materially affected, or were reasonably likely to materially affect, the company’s internal control over financial reporting.

PART II

OTHER INFORMATION

Item 1.   Legal Proceedings

None

Item 1A.   Risk Factors

Chevron is a major fully integrated petroleum company with a diversified business portfolio, strong balance sheet, and history of generating sufficient cash to fund capital and exploratory expenditures and to pay dividends. Nevertheless, some inherent risks could materially impact the company’s financial results of operations or financial condition.

Information about risk factors for the three months ended June 30, 2008, does not differ materially from that set forth in Part I, Item 1A, of Chevron’s 2007 Annual Report on Form 10-K/A.

36

Item 2.   Unregistered Sales of Equity Securities and Use of Proceeds

CHEVRON CORPORATION

ISSUER PURCHASES OF EQUITY SECURITIES

							Maximum
	Total				Total Number of		Number of Shares
	Number of		Average		Shares Purchased as		that May Yet Be
	Shares		Price Paid		Part of Publicly		Purchased Under
Period	Purchased(1)		per Share		Announced Program		the Program
April 1-30, 2008		3,092,614		88.40		2,760,000		—
May 1-31, 2008		8,671,760		99.27		8,150,000		—
June 1-30, 2008		9,735,675		98.84		9,588,950		—
Total		21,500,049		97.51		20,498,950		(2	)

(1)

Includes 69,885 common shares repurchased during the three-month period ended June 30, 2008, from company employees for required personal income tax withholdings on the exercise of the stock options issued to management and employees under the company’s long-term incentive plans. Also includes 931,214 shares delivered or attested to in satisfaction of the exercise price by holders of certain former Texaco Inc. employee stock options exercised during the three-month period ended June 30, 2008.

(2)

In September 2007, the company authorized common stock repurchases of up to $15 billion that may be made from time to time at prevailing prices as permitted by securities laws and other requirements, and subject to market conditions and other factors. The program will occur over a period of up to three years and may be discontinued at any time. Through June 30, 2008, $6.1 billion had been expended to repurchase 67,446,969 shares since the common stock repurchase program began.

Item 4.   Submission of Matters to a Vote of Security Holders

The following matters were submitted to a vote of stockholders at the Annual Meeting on May 28, 2008.

	Number of Shares
	Voted For		Voted Against		Abstain
1. Election of Directors
Samuel H. Armacost		1,743,417,440		44,810,834		31,807,962
Linnet F. Deily		1,713,150,542		75,342,094		31,562,079
Robert E. Denham		1,744,269,018		43,844,360		31,941,339
Robert J. Eaton		1,755,515,473		33,108,822		31,430,421
Sam Ginn		1,754,511,498		33,295,139		32,248,080
Franklyn G. Jenifer		1,754,709,310		33,051,397		32,294,009
James L. Jones		1,765,116,359		22,915,465		32,022,892
Sam Nunn		1,732,544,395		56,199,932		31,291,909
David J. O’Reilly		1,757,764,953		30,689,648		31,581,638
Donald B. Rice		1,762,966,572		25,689,599		31,380,065
Peter J. Robertson		1,760,932,844		28,525,320		30,578,072
Kevin W. Sharer		1,757,173,631		31,496,112		31,384,972
Charles R. Shoemate		1,766,031,875		22,044,298		31,978,542
Ronald D. Sugar		1,766,253,958		22,179,740		31,621,017
Carl Ware		1,766,064,255		22,859,652		31,130,810

37

	Number of Shares
							Represent Broker
	Voted For		Voted Against		Abstain		Non-Votes
2. Ratification of Independent Registered Public Accounting Firm		1,763,587,543		27,427,886		29,039,287		—
3. Board Proposal to Amend Company’s Restated Certificate of Incorporation to Increase the Number of Authorized Shares of Chevron Common Stock		1,692,925,211		95,627,717		31,501,504		—
4. Stockholder Proposal to Adopt Policy to Separate the CEO/Chairman Positions		213,611,721		1,238,892,898		34,543,318		333,006,780
5. Stockholder Proposal to Adopt Policy and Report on Human Rights		357,594,229		922,270,421		207,183,571		333,006,496
6. Stockholder Proposal to Report on the Environmental Impact of Canadian Oil Sands Operations		367,412,563		916,958,818		202,675,856		333,007,480
7. Stockholder Proposal to Adopt Goals and Report on Greenhouse Gas Emissions		131,853,279		1,133,496,557		221,698,101		333,006,780
8. Stockholder Proposal to Review and Report on Guidelines for Country Selection		113,077,141		1,162,223,669		211,747,411		333,006,496
9. Stockholder Proposal to Report on Host Country Laws		105,873,057		1,175,936,983		205,238,181		333,006,496

Item 6.   Exhibits

Exhibit
Number	Description
(3.1)	Restated Certificate of Incorporation of Chevron Corporation, dated May 30, 2008
(4)	Pursuant to the Instructions to Exhibits, certain instruments defining the rights of holders of long-term debt securities of the company and its consolidated subsidiaries are not filed because the total amount of securities authorized under any such instrument does not exceed 10 percent of the total assets of the corporation and its subsidiaries on a consolidated basis. A copy of such instrument will be furnished to the Commission upon request.
(12.1)	Computation of Ratio of Earnings to Fixed Charges
(31.1)	Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Executive Officer
(31.2)	Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Financial Officer
(32.1)	Section 1350 Certification by the company’s Chief Executive Officer
(32.2)	Section 1350 Certification by the company’s Chief Financial Officer

38

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

Chevron Corporation
(Registrant)

/s/  M.A. Humphrey

M.A. Humphrey, Vice President and Comptroller

(Principal Accounting Officer and

Duly Authorized Officer)

Date: August 7, 2008

39

EXHIBIT INDEX

Exhibit
Number	Description
(3.1)*	Restated Certificate of Incorporation of Chevron Corporation, dated May 30, 2008
(4)	Pursuant to the Instructions to Exhibits, certain instruments defining the rights of holders of long-term debt securities of the company and its consolidated subsidiaries are not filed because the total amount of securities authorized under any such instrument does not exceed 10 percent of the total assets of the corporation and its subsidiaries on a consolidated basis. A copy of such instrument will be furnished to the Commission upon request.
(12.1)*	Computation of Ratio of Earnings to Fixed Charges
(31.1)*	Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Executive Officer
(31.2)*	Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Financial Officer
(32.1)*	Section 1350 Certification by the company’s Chief Executive Officer
(32.2)*	Section 1350 Certification by the company’s Chief Financial Officer

* Filed herewith.

Copies of above exhibits not contained herein are available to any security holder upon written request to the Corporate Governance Department, Chevron Corporation, 6001 Bollinger Canyon Road, San Ramon, California 94583-2324.

40