e10vq
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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 September 30, 2009
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
incorporation or organization)
  (I.R.S. Employer
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 has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).  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. (Check one):
 
             
Large accelerated filer þ
  Accelerated filer o   Non-accelerated filer o
(Do not check if a smaller reporting company)
  Smaller reporting company o
 
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 September 30, 2009
 
Common stock, $.75 par value
  2,006,267,842
 


 

 
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  
 
  Consolidated Financial Statements —        
    Consolidated Statement of Income for the Three and Nine Months Ended September 30, 2009, and 2008     3  
    Consolidated Statement of Comprehensive Income for the Three and Nine Months Ended September 30, 2009, and 2008     4  
    Consolidated Balance Sheet at September 30, 2009, and December 31, 2008     5  
    Consolidated Statement of Cash Flows for the Nine Months Ended September 30, 2009, and 2008     6  
    Notes to Consolidated Financial Statements     7-22  
  Management’s Discussion and Analysis of Financial Condition and Results of Operations     23-38  
  Quantitative and Qualitative Disclosures About Market Risk     39  
  Controls and Procedures     39  
 
  Legal Proceedings     39  
  Risk Factors     39  
  Unregistered Sales of Equity Securities and Use of Proceeds     40  
  Exhibits     41  
    42  
Exhibits:
  Computation of Ratio of Earnings to Fixed Charges     44  
Rule 13a-14(a)/15d-14(a) Certifications
    45-46  
Section 1350 Certifications
    47-48  
 EX-12.1
 EX-31.1
 EX-31.2
 EX-32.1
 EX-32.2
 EX-101 INSTANCE DOCUMENT
 EX-101 SCHEMA DOCUMENT
 EX-101 CALCULATION LINKBASE DOCUMENT
 EX-101 LABELS LINKBASE DOCUMENT
 EX-101 PRESENTATION LINKBASE DOCUMENT
 EX-101 DEFINITION LINKBASE DOCUMENT


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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 the company’s 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 or regulators; timing of exploration expenses; timing of crude-oil liftings, 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 the Organization of Petroleum Exporting Countries (OPEC); 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 30 and 31 of the company’s 2008 Annual Report on Form 10-K. 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.


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PART I.
 
FINANCIAL INFORMATION
 
Item 1.   Consolidated Financial Statements
 
CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF INCOME
(Unaudited)
 
                                 
    Three Months Ended
    Nine Months Ended
 
    September 30     September 30  
    2009     2008     2009     2008  
    (Millions of dollars, except per-share amounts)  
 
Revenues and Other Income
                               
Sales and other operating revenues*
  $ 45,180     $ 76,192     $ 119,814     $ 221,813  
Income from equity affiliates
    1,072       1,673       2,418       4,480  
Other income
    373       1,002       728       1,509  
                                 
Total Revenues and Other Income
    46,625       78,867       122,960       227,802  
                                 
Costs and Other Deductions
                               
Purchased crude oil and products
    26,969       49,238       71,047       147,822  
Operating expenses
    4,403       5,676       12,958       15,379  
Selling, general and administrative expenses
    1,177       1,278       3,197       4,264  
Exploration expenses
    242       271       1,061       831  
Depreciation, depletion and amortization
    2,988       2,449       8,954       6,939  
Taxes other than on income*
    4,644       5,614       13,008       16,756  
Interest and debt expense
    14             28        
                                 
Total Costs and Other Deductions
    40,437       64,526       110,253       191,991  
                                 
Income Before Income Tax Expense
    6,188       14,341       12,707       35,811  
Income Tax Expense
    2,342       6,416       5,246       16,681  
                                 
Net Income
    3,846       7,925       7,461       19,130  
Less: Net income attributable to noncontrolling interests
    15       32       48       94  
                                 
Net Income Attributable to Chevron Corporation
  $ 3,831     $ 7,893     $ 7,413     $ 19,036  
                                 
Per Share of Common Stock:
                               
Net Income Attributable to Chevron Corporation
                               
— Basic
  $ 1.92     $ 3.88     $ 3.72     $ 9.29  
— Diluted
  $ 1.92     $ 3.85     $ 3.71     $ 9.23  
Dividends
  $ 0.68     $ 0.65     $ 1.98     $ 1.88  
Weighted Average Number of Shares Outstanding (000s)
                               
— Basic
    1,992,452        2,032,433        1,991,733        2,049,812  
— Diluted
    2,000,586        2,044,616        1,999,925        2,063,149  
                                 
                               
* Includes excise, value-added and similar taxes:
  $ 2,079     $ 2,577     $ 6,023     $ 7,766  
 
See accompanying notes to consolidated financial statements.


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CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
(Unaudited)
 
                                 
    Three Months Ended
    Nine Months Ended
 
    September 30     September 30  
    2009     2008     2009     2008  
    (Millions of dollars)  
 
Net Income
  $ 3,846     $ 7,925     $ 7,461     $ 19,130  
                                 
Currency translation adjustment
    31       (67 )     44       (84 )
Unrealized holding gain (loss) on securities:
                               
Net gain (loss) arising during period
    8       (13 )     3       (5 )
Derivatives:
                               
Net derivatives gain (loss) on hedge transactions
    7       126       (65 )     74  
Reclassification to net income of net realized (gain) loss
    (9 )     4       (25 )     15  
Income taxes on derivatives transactions
    1       (44 )     31       (32 )
                                 
Total
    (1 )     86       (59 )     57  
Defined benefit plans:
                               
Actuarial loss:
                               
Amortization to net income of net actuarial loss
    136       62       451       187  
Prior service cost:
                               
Amortization to net income of net prior service credits
    (15 )     (16 )     (49 )     (47 )
Defined benefit plans sponsored by equity affiliates
    5       7       10       22  
Income taxes on defined benefit plans
    (45 )     (17 )     (152 )     (65 )
                                 
Total
    81       36       260       97  
                                 
Other Comprehensive Gain, Net of Tax
    119       42       248       65  
                                 
Comprehensive Income
    3,965       7,967       7,709       19,195  
Comprehensive income attributable to noncontrolling interests
    (15 )     (32 )     (48 )     (94 )
                                 
Comprehensive Income Attributable to Chevron Corporation
  $ 3,950     $ 7,935     $ 7,661     $ 19,101  
                                 
 
See accompanying notes to consolidated financial statements.


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CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEET
(Unaudited)
 
                 
    At September 30
  At December 31
    2009   2008
    (Millions of dollars, except
    per-share amounts)
 
ASSETS
Cash and cash equivalents
    $   7,568       $   9,347  
Marketable securities
    121       213  
Accounts and notes receivable, net
    17,070       15,856  
Inventories:
               
Crude oil and petroleum products
    4,652       5,175  
Chemicals
    333       459  
Materials, supplies and other
    1,338       1,220  
                 
Total inventories
    6,323       6,854  
Prepaid expenses and other current assets
    4,459       4,200  
                 
Total Current Assets
    35,541       36,470  
Long-term receivables, net
    2,394       2,413  
Investments and advances
    21,564       20,920  
Properties, plant and equipment, at cost
    183,547       173,299  
Less: Accumulated depreciation, depletion and amortization
    89,290       81,519  
                 
Properties, plant and equipment, net
    94,257       91,780  
Deferred charges and other assets
    3,870       4,711  
Goodwill
    4,619       4,619  
Assets held for sale
    316       252  
                 
Total Assets
    $162,561       $161,165  
                 
 
LIABILITIES AND EQUITY
Short-term debt
    $240       $2,818  
Accounts payable
    15,715       16,580  
Accrued liabilities
    5,501       8,077  
Federal and other taxes on income
    2,562       3,079  
Other taxes payable
    1,375       1,469  
                 
Total Current Liabilities
    25,393       32,023  
Long-term debt
    9,973       5,742  
Capital lease obligations
    329       341  
Deferred credits and other noncurrent obligations
    17,497       17,678  
Noncurrent deferred income taxes
    11,738       11,539  
Reserves for employee benefit plans
    6,409       6,725  
                 
Total Liabilities
    71,339       74,048  
                 
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 September 30, 2009, and December 31, 2008)
    1,832       1,832  
Capital in excess of par value
    14,584       14,448  
Retained earnings
    104,575       101,102  
Accumulated other comprehensive loss
    (3,676 )     (3,924 )
Deferred compensation and benefit plan trust
    (414 )     (434 )
Treasury stock, at cost (436,408,738 and 438,444,795 shares at September 30, 2009, and December 31, 2008, respectively)
    (26,255 )     (26,376 )
                 
Total Chevron Corporation Stockholders’ Equity
    90,646       86,648  
Noncontrolling interests
    576       469  
                 
Total Equity
    91,222       87,117  
                 
Total Liabilities and Equity
    $162,561       $161,165  
                 
 
See accompanying notes to consolidated financial statements.


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CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF CASH FLOWS
(Unaudited)
 
                 
    Nine Months Ended
 
    September 30  
    2009     2008  
    (Millions of dollars)  
 
Operating Activities
               
Net Income Attributable to Chevron Corporation
  $ 7,413     $ 19,036  
Adjustments
               
Depreciation, depletion and amortization
    8,954       6,939  
Dry hole expense
    481       287  
Distributions less than income from equity affiliates
    (510 )     (278 )
Net before-tax gains on asset retirements and sales
    (1,083 )     (757 )
Net foreign currency effects
    481       (74 )
Deferred income tax provision
    335       37  
Net increase in operating working capital
    (2,993 )     (713 )
Net income attributable to noncontrolling interests
    48       94  
Increase in long-term receivables
    (288 )     (221 )
Decrease (increase) in other deferred charges
    131       (70 )
Cash contributions to employee pension plans
    (860 )     (169 )
Other
    244       313  
                 
Net Cash Provided by Operating Activities
    12,353       24,424  
                 
Investing Activities
               
Capital expenditures
    (14,488 )     (13,632 )
Proceeds and deposits related to asset sales
    2,132       1,384  
Net sales of marketable securities
    113       351  
Repayment of loans by equity affiliates
    167       169  
Net sales of other short-term investments
    153       359  
                 
Net Cash Used for Investing Activities
    (11,923 )     (11,369 )
                 
Financing Activities
               
Net (payments) borrowings of short-term obligations
    (3,258 )     661  
Proceeds from issuance of long-term debt
    5,339        
Repayments of long-term debt and other financing obligations
    (461 )     (926 )
Cash dividends
    (3,945 )     (3,861 )
Distributions to noncontrolling interests
    (37 )     (88 )
Net sales (purchases) of treasury shares
    86       (5,530 )
                 
Net Cash Used for Financing Activities
    (2,276 )     (9,744 )
                 
Effect of Exchange Rate Changes on Cash and Cash Equivalents
    67       (37 )
                 
Net Change in Cash and Cash Equivalents
    (1,779 )     3,274  
Cash and Cash Equivalents at January 1
    9,347       7,362  
                 
Cash and Cash Equivalents at September 30
  $ 7,568     $ 10,636  
                 
 
See accompanying notes to consolidated financial statements.


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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 an independent registered public accounting firm. 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. The results for the three- and nine-month periods ended September 30, 2009, are not necessarily indicative of future financial results. The term “earnings” is defined as net income attributable to Chevron Corporation.
 
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 2008 Annual Report on Form 10-K.
 
Effective with the quarter ending September 30, 2009, the company implemented the Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) system. The ASC supersedes literature of the FASB, Emerging Issues Task Force and other sources. The ASC did not change U.S. generally accepted accounting principles. Refer also to Note 15 beginning on page 21 for discussion of ASC.
 
Events subsequent to September 30, 2009, were evaluated until the time of the Form 10-Q filing with the Securities and Exchange Commission on November 5, 2009.
 
Earnings for the third quarter 2009 included $400 million of after-tax gains from asset sales and tax items related to an upstream project in Australia. Earnings for the first nine months of 2009 also included $540 million of after-tax gains reported in the first half of the year on sales of marketing businesses outside the United States.
 
Earnings for the third quarter and nine months of 2008 included approximately $400 million of expenses associated with damage to upstream facilities in the U.S. Gulf of Mexico caused by hurricanes. Largely offsetting the impact of these expenses were gains of about $350 million on U.S. upstream asset sales.
 
Note 2.  Noncontrolling Interests
 
The company adopted the accounting standard for noncontrolling interests in consolidated financial statements effective January 1, 2009, and retroactive to the earliest period presented. Ownership interests in the company’s subsidiaries held by parties other than the parent are presented separately from the parent’s equity on the Consolidated Balance Sheet. The amount of consolidated net income attributable to the parent and the noncontrolling interests are both presented on the face of the Consolidated Statement of Income.
 
Activity for the equity attributable to noncontrolling interests for the first nine months of 2009 and 2008 is as follows:
 
                                                 
    2009   2008
    Chevron Corporation
  Noncontrolling
  Total
  Chevron Corporation
  Noncontrolling
  Total
    Stockholders’ Equity   Interest   Equity   Stockholders’ Equity   Interest   Equity
    (Millions of dollars)
 
Balance at January 1
    $86,648       $469       $87,117       $77,088       $204       $77,292  
Net income
    7,413       48       7,461       19,036       94       19,130  
Dividends
    (3,945 )           (3,945 )     (3,861 )           (3,861 )
Distributions to noncontrolling interests
          (37 )     (37 )           (88 )     (88 )
Treasury shares, net
    121             121       (5,523 )           (5,523 )
Other changes, net*
    409       96       505       214       1       215  
                                                 
Balance at September 30
    $90,646       $576       $91,222       $86,954       $211       $87,165  
                                                 
 
 
* Includes components of comprehensive income, which are disclosed separately in the Consolidated Statement of Comprehensive Income.


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
 
Note 3.  Information Relating to the Consolidated Statement of Cash Flows
 
The “Net increase in operating working capital” was composed of the following operating changes:
 
                 
    Nine Months Ended
 
    September 30  
    2009     2008  
    (Millions of dollars)  
 
Increase in accounts and notes receivable
  $ (877 )   $ (2,559 )
Decrease (increase) in inventories
    356       (979 )
Increase in prepaid expenses and other current assets
    (216 )     (461 )
(Decrease) increase in accounts payable and accrued liabilities
    (1,597 )     1,507  
(Decrease) increase in income and other taxes payable
    (659 )     1,779  
                 
Net increase in operating working capital
  $ (2,993 )   $ (713 )
                 
 
The “Net increase in operating working capital” includes reductions of $11 million and $102 million for excess income tax benefits associated with stock options exercised during the nine months ended September 30, 2009, and 2008, respectively. These amounts are offset by an equal amount in “Net sales (purchases) of treasury shares.”
 
“Net Cash Provided by Operating Activities” included the following cash payments for interest on debt and for income taxes:
 
                 
    Nine Months Ended
 
    September 30  
    2009     2008  
    (Millions of dollars)  
 
Interest on debt (net of capitalized interest)
  $ 11     $  
Income taxes
    4,825       14,298  
 
The “Net sales of marketable securities” consisted of the following gross amounts:
 
                 
    Nine Months Ended
 
    September 30  
    2009     2008  
    (Millions of dollars)  
 
Marketable securities purchased
  $ (24 )   $ (3,232 )
Marketable securities sold
    137       3,583  
                 
Net sales of marketable securities
  $ 113     $ 351  
                 
 
The “Net sales (purchases) of treasury shares” represents the cost of common shares acquired less the cost of shares issued for share-based compensation plans. Net sales totaled $86 million in the first nine months of 2009 and net purchases totaled $5.5 billion in the 2008 period. Purchases in the 2008 period were under the company’s stock repurchase program initiated in September 2007. No purchases were made under the program in the 2009 period.


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
The major components of “Capital expenditures” and the reconciliation of this amount to the capital and exploratory expenditures, including equity affiliates, are as follows:
 
                 
    Nine Months Ended
 
    September 30  
    2009     2008  
    (Millions of dollars)  
 
Additions to properties, plant and equipment
  $ 13,542     $ 12,812  
Additions to investments
    793       715  
Current-year dry-hole expenditures
    399       239  
Payments for other liabilities and assets, net
    (246 )     (134 )
                 
Capital expenditures
    14,488       13,632  
Expensed exploration expenditures
    580       544  
Assets acquired through capital-lease obligations
    20       14  
                 
Capital and exploratory expenditures, excluding equity affiliates
    15,088       14,190  
Company’s share of expenditures by equity affiliates
    923       1,587  
                 
Capital and exploratory expenditures, including equity affiliates
  $ 16,011     $ 15,777  
                 
 
“Additions to properties, plant and equipment” in the 2009 period include $2 billion for a cash payment related to the extension of an upstream concession agreement.
 
Note 4.  Operating Segments and Geographic Data
 
Although each subsidiary of Chevron is responsible for its own affairs, Chevron Corporation manages its investments in these subsidiaries and their affiliates. 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 the accounting standards.
 
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 the accounting standards). 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 the accounting standards 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.
 
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 and technology companies.


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
The company’s primary country of operation is the United States of America, its country of domicile. Other components of the company’s operations are reported as “International” (outside the United States).
 
Segment Earnings The company evaluates the performance of its operating segments on an after-tax basis, without considering the effects of debt financing interest expense or investment interest income, both of which are managed by the company on a worldwide basis. Corporate administrative costs and assets are not allocated to the operating segments. However, operating segments are billed for the direct use of corporate services. Nonbillable costs remain at the corporate level in “All Other.” Earnings by major operating area for the three- and nine-month periods ended September 30, 2009 and 2008 are presented in the following table:
 
Segment Earnings
 
                                 
    Three Months Ended
    Nine Months Ended
 
    September 30     September 30  
    2009     2008     2009     2008  
    (Millions of dollars)  
 
Upstream
                               
United States
  $ 878     $ 2,187     $ 1,172     $ 5,977  
International
    2,762       3,995       5,256       12,581  
                                 
Total Upstream
    3,640       6,182       6,428       18,558  
                                 
Downstream
                               
United States
    34       1,014       72       336  
International
    160       817       1,106       1,013  
                                 
Total Downstream
    194       1,831       1,178       1,349  
                                 
Chemicals
                               
United States
    105       30       165       32  
International
    59       40       146       122  
                                 
Total Chemicals
    164       70       311       154  
                                 
Total Segment Earnings
    3,998       8,083       7,917       20,061  
                                 
All Other
                               
Interest Expense
    (11 )           (22 )      
Interest Income
    10       52       36       157  
Other
    (166 )     (242 )     (518 )     (1,182 )
                                 
Net Income Attributable to Chevron Corporation
  $ 3,831     $ 7,893     $ 7,413     $ 19,036  
                                 


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
Segment Assets Segment assets do not include intercompany investments or intercompany receivables. “All Other” assets in 2009 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 September 30, 2009, and December 31, 2008, are as follows:
 
Segment Assets
 
                 
    At September 30
  At December 31
    2009   2008
    (Millions of dollars)
 
Upstream
               
United States
    $  24,711       $  26,071  
International
    74,125       72,530  
Goodwill
    4,619       4,619  
                 
Total Upstream
    103,455       103,220  
                 
Downstream
               
United States
    17,697       15,869  
International
    25,080       23,572  
                 
Total Downstream
    42,777       39,441  
                 
Chemicals
               
United States
    2,736       2,535  
International
    1,051       1,086  
                 
Total Chemicals
    3,787       3,621  
                 
Total Segment Assets
    150,019       146,282  
                 
All Other
               
United States
    6,804       8,984  
International
    5,738       5,899  
                 
Total All Other
    12,542       14,883  
                 
Total Assets — United States
    51,948       53,459  
Total Assets — International
    105,994       103,087  
Goodwill
    4,619       4,619  
                 
Total Assets
    $162,561       $161,165  
                 
 
Segment Sales and Other Operating Revenues Operating-segment sales and other operating revenues, including internal transfers, for the three- and nine-month periods ended September 30, 2009 and 2008, are presented in the table on the following page. Products are transferred between operating segments at internal product values that approximate market prices. Revenues for the upstream segment are derived primarily from the production and sale of crude oil and natural gas, as well as the sale of third-party production of natural gas. Revenues for the downstream segment are derived from the refining and marketing of petroleum products such as gasoline, jet fuel, gas oils, lubricants, residual fuel oils and other products derived from crude oil. This segment also generates revenues from the 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, power generation businesses, insurance operations, real estate activities and technology companies.


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
Sales and Other Operating Revenues
 
                                 
    Three Months Ended
    Nine Months Ended
 
    September 30     September 30  
    2009     2008     2009     2008  
    (Millions of dollars)  
 
Upstream
                               
United States
  $ 4,964     $ 11,036     $ 13,596     $ 32,980  
International
    8,321       12,295       22,256       36,514  
                                 
Sub-total
    13,285       23,331       35,852       69,494  
Intersegment Elimination — United States
    (3,008 )     (4,461 )     (6,910 )     (13,094 )
Intersegment Elimination — International
    (4,864 )     (6,840 )     (12,695 )     (21,009 )
                                 
Total Upstream
    5,413       12,030       16,247       35,391  
                                 
Downstream
                               
United States
    17,992       27,692       44,595       77,803  
International
    21,224       35,924       57,491       107,086  
                                 
Sub-total
    39,216       63,616       102,086       184,889  
Intersegment Elimination — United States
    (46 )     (126 )     (136 )     (377 )
Intersegment Elimination — International
    (34 )     (44 )     (73 )     (107 )
                                 
Total Downstream
    39,136       63,446       101,877       184,405  
                                 
Chemicals
                               
United States
    131       146       361       424  
International
    389       443       1,051       1,265  
                                 
Sub-total
    520       589       1,412       1,689  
Intersegment Elimination — United States
    (56 )     (60 )     (151 )     (189 )
Intersegment Elimination — International
    (35 )     (43 )     (99 )     (122 )
                                 
Total Chemicals
    429       486       1,162       1,378  
                                 
All Other
                               
United States
    474       448       1,181       1,212  
International
    18       19       47       56  
                                 
Sub-total
    492       467       1,228       1,268  
Intersegment Elimination — United States
    (281 )     (230 )     (679 )     (611 )
Intersegment Elimination — International
    (9 )     (7 )     (21 )     (18 )
                                 
Total All Other
    202       230       528       639  
                                 
Sales and Other Operating Revenues
                               
United States
    23,561       39,322       59,733       112,419  
International
    29,952       48,681       80,845       144,921  
                                 
Sub-total
    53,513       88,003       140,578       257,340  
Intersegment Elimination — United States
    (3,391 )     (4,877 )     (7,876 )     (14,271 )
Intersegment Elimination — International
    (4,942 )     (6,934 )     (12,888 )     (21,256 )
                                 
Total Sales and Other Operating Revenues
  $ 45,180     $ 76,192     $ 119,814     $ 221,813  
                                 


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
 
Note 5.  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, and supply and distribution of products derived from petroleum, excluding most of the regulated pipeline operations of Chevron. CUSA also holds the company’s investment in the Chevron Phillips Chemical Company LLC joint venture, which is accounted for using the equity method.
 
During 2008, Chevron implemented legal reorganizations in which certain Chevron subsidiaries transferred assets to or under CUSA. The summarized financial information for CUSA and its consolidated subsidiaries presented in the table below gives retroactive effect to the reorganizations as if they had occurred on January 1, 2008. However, the financial information below may not reflect the financial position and operating results in the future or the historical results in the period presented if the reorganization actually had occurred on that date. The summarized financial information for CUSA and its consolidated subsidiaries is as follows:
 
                 
    Nine Months Ended
 
    September 30  
    2009     2008  
    (Millions of dollars)  
 
Sales and other operating revenues
  $ 86,522     $ 166,627  
Costs and other deductions
    85,461       159,855  
Net income attributable to Chevron U.S.A. Inc. 
    852       4,636  
 
                 
    At September 30
  At December 31
    2009   2008
    (Millions of dollars)
 
Current assets
    $32,975       $32,760  
Other assets
    32,358       31,806  
Current liabilities
    13,806       14,322  
Other liabilities
    14,482       14,049  
                 
Total Chevron U.S.A. Inc. net equity
    $37,045       $36,195  
                 
Memo: Total debt
    $  6,985       $  6,813  
 
The amount for the nine months ended September 30, 2008, for “Net income attributable to Chevron U.S.A. Inc” and the balances at December 31, 2008, for “Other liabilities” and “Total Chevron U.S.A. Inc. net equity” have been adjusted by immaterial amounts associated with the allocation of income-tax liabilities among Chevron Corporation subsidiaries.
 
Note 6.  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 as follows:
 
                                 
    Three Months Ended
    Nine Months Ended
 
    September 30     September 30  
    2009     2008     2009     2008  
    (Millions of dollars)     (Millions of dollars)  
 
Sales and other operating revenues
  $ 153     $ 294     $ 492     $ 795  
Costs and other deductions
    186       269       565       722  
Net (loss) income attributable to Chevron Transport Corporation
    (34 )     25       (73 )     115  


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
                 
    At September 30
  At December 31
    2009   2008
    (Millions of dollars)
 
Current assets
    $420       $482  
Other assets
    169       172  
Current liabilities
    104       98  
Other liabilities
    89       88  
                 
Total Chevron Transport Corporation net equity
    $396       $468  
                 
 
There were no restrictions on CTC’s ability to pay dividends or make loans or advances at September 30, 2009.
 
Note 7.  Income Taxes
 
Taxes on income for the third quarter and first nine months of 2009 were $2.3 billion and $5.2 billion, respectively, compared with $6.4 billion and $16.7 billion for the corresponding periods in 2008. The associated effective tax rates (calculated as the amount of Income Tax Expense divided by Income Before Income Tax Expense) for the third quarters of 2009 and 2008 were 38 percent and 45 percent, respectively. For the comparative nine-month periods, the effective tax rates were 41 percent and 47 percent, respectively.
 
The decline in the effective tax rates between the quarterly and nine-month periods was generally associated with the same factors. These factors included the effect in 2009 of relatively low tax rates on asset sales and deferred-tax benefits, both related to an international upstream project. In addition, a greater proportion of before-tax income was earned in 2009 by equity affiliates than in 2008. (Equity-affiliate income is reported as a single amount on an after-tax basis on the Consolidated Statement of Income.)
 
Note 8.  Employee Benefits
 
Chevron has defined-benefit pension plans for many employees. The company typically prefunds defined-benefit plans as required by local regulations or in certain situations where 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.


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
The components of net periodic benefit costs for 2009 and 2008 are as follows:
 
                                 
    Three Months Ended
    Nine Months Ended
 
    September 30     September 30  
    2009     2008     2009     2008  
    (Millions of dollars)     (Millions of dollars)  
 
Pension Benefits
                               
United States
                               
Service cost
  $ 66     $ 63     $ 199     $ 188  
Interest cost
    121       125       361       374  
Expected return on plan assets
    (99 )     (149 )     (296 )     (445 )
Amortization of prior-service credits
    (1 )     (1 )     (5 )     (5 )
Amortization of actuarial losses
    74       14       223       44  
Settlement losses
    25       19       126       58  
                                 
Total United States
    186       71       608       214  
                                 
International
                               
Service cost
    31       34       90       102  
Interest cost
    76       81       215       224  
Expected return on plan assets
    (52 )     (76 )     (148 )     (209 )
Amortization of prior-service costs
    6       6       17       19  
Amortization of actuarial losses
    30       19       81       56  
Termination costs
                      1  
                                 
Total International
    91       64       255       193  
                                 
Net Periodic Pension Benefit Costs
  $ 277     $ 135     $ 863     $ 407  
                                 
Other Benefits*
                               
Service cost
  $ 9     $ 7     $ 25     $ 63  
Interest cost
    45       45       134       134  
Amortization of prior-service credits
    (20 )     (21 )     (61 )     (61 )
Amortization of actuarial losses
    6       10       20       29  
Curtailment gains
                (5 )      
                                 
Net Periodic Other Benefit Costs
  $ 40     $ 41     $ 113     $ 165  
                                 
 
 
* 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 2008, the company estimated it would contribute $800 million to employee pension plans during 2009 (composed of $550 million for the U.S. plans and $250 million for the international plans). Through September 30, 2009, a total of $860 million was contributed (including $741 million to the U.S. plans). Total contributions for the full year are currently estimated at $1 billion ($750 million for the U.S. plans and $250 million for the international plans). Actual contribution amounts are dependent upon investment returns, changes in pension obligations, regulatory environments and other economic factors. Additional funding may ultimately be required if investment returns are insufficient to offset increases in plan obligations.
 
During the first nine months of 2009, the company contributed $140 million to its other postretirement benefit plans. The company anticipates contributing about $70 million during the remainder of 2009.


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
 
Note 9.  Accounting for Suspended Exploratory Wells
 
Accounting standards for the cost of exploratory wells provide that an exploratory well continues to be capitalized after the completion of drilling when (a) the well has found a sufficient quantity of reserves to justify completion as a producing well and (b) the enterprise is making sufficient progress assessing the reserves and the economic and operating viability of the project. If either condition is not met or if the company obtains information that raises substantial doubt about the economic or operational viability of the project, the exploratory well would be assumed to be impaired, and its costs, net of any salvage value, would be charged to expense. The company’s capitalized cost of suspended wells at September 30, 2009, was $2.3 billion, an increase of $173 million from year-end 2008. For the category of exploratory well costs at year-end 2008 that were suspended more than one year, a total of $76 million was expensed in the first nine months of 2009.
 
Note 10.  Litigation
 
MTBE Chevron and many other companies in the petroleum industry have used methyl tertiary butyl ether (MTBE) as a gasoline additive. Chevron is a party to 50 pending lawsuits and claims, the majority of which involve numerous other petroleum marketers and refiners. Resolution of these lawsuits and claims may ultimately require the company to correct or ameliorate the alleged effects on the environment of prior release of MTBE by the company or other parties. Additional lawsuits and claims related to the use of MTBE, including personal-injury claims, may be filed in the future. The company’s ultimate exposure related to pending lawsuits and claims is not 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.
 
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, health care systems, and additional infrastructure for Petroecuador. The engineer’s report also asserted 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


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
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 submitted a rebuttal to the report in which it asked the court to strike the report in its entirety. In November 2008, the engineer revised the report and, without additional evidence, recommended an increase in the financial compensation for purported damages to a total of $18.9 billion and an increase in the assessment for purported unjust enrichment to a total of $8.4 billion. Chevron submitted a rebuttal to the revised report, which the court dismissed. In September 2009, following the disclosure by Chevron of evidence that the judge participated in meetings in which businesspeople and individuals holding themselves out as government officials discussed the case and its likely outcome, the judge presiding over the case petitioned to be recused. In late September 2009, the judge was recused, and in October 2009, the full chamber of the provincial court affirmed the recusal, resulting in the appointment of a new judge. Chevron filed motions to annul all of the rulings made by the prior judge, but the new judge denied these motions. The court has completed most of the procedural aspects of the case and could render a judgment at any time. Chevron will continue a vigorous defense of any attempted imposition of liability.
 
In the event of an adverse judgment, Chevron would expect to pursue its appeals and vigorously defend against enforcement of any such judgment; therefore, the ultimate outcome — and any financial effect on Chevron — remains uncertain. Management does not believe an estimate of a reasonably possible loss (or a range of loss) can be made in this case. Due to the defects associated with the engineer’s report, management does not believe the report 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 11.  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 September 2009, 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 had to be asserted by February 2009 for Equilon indemnities and must be asserted no later than February 2012 for Motiva indemnities. Under the terms of these indemnities, there is no maximum limit on the amount of potential future payments. In February 2009, Shell delivered a letter to the company purporting to preserve unmatured claims for certain Equilon indemnities. The letter itself provides no estimate of the ultimate claim amount, and management does not believe the letter or any other information


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
provides a basis to estimate the amount, if any, of a range of loss or potential range of loss with respect to the Equilon or the Motiva indemnities. The company posts no assets as collateral and has made no payments under the indemnities.
 
The amounts payable for the indemnities described on page 17 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 September 30, 2009.
 
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.
 
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 derivative activities.
 
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.


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
 
Note 12.  Fair Value Measurements
 
Accounting standards on fair-value measurement establish a framework for measuring fair value and stipulate disclosures about fair-value measurements. The standards apply to recurring and nonrecurring financial and nonfinancial assets and liabilities that require or permit fair-value measurements. A new accounting standard became effective for Chevron on January 1, 2008, for all financial assets and liabilities and recurring nonfinancial assets and liabilities. On January 1, 2009, the standard became effective for nonrecurring nonfinancial assets and liabilities. Among the required disclosures is the fair-value hierarchy of inputs the company uses to value an asset or a liability. The three levels of the fair-value hierarchy are described as follows:
 
Level 1: Quoted prices (unadjusted) in active markets for identical assets and liabilities. For the company, Level 1 inputs include exchange-traded futures contracts for which the parties are willing to transact at the exchange-quoted price and marketable securities that are actively traded.
 
Level 2: Inputs other than Level 1 that are observable, either directly or indirectly. For the company, Level 2 inputs include quoted prices for similar assets or liabilities, prices obtained through third-party broker quotes and prices that can be corroborated with other observable inputs for substantially the complete term of a contract.
 
Level 3: Unobservable inputs. The company does not use Level 3 inputs for any of its recurring fair-value measurements. Level 3 inputs may be required for the determination of fair value associated with certain nonrecurring measurements of nonfinancial assets and liabilities. In the third quarter the company used Level 3 inputs to determine the fair value of nonrecurring nonfinancial assets.
 
The fair value hierarchy for recurring assets and liabilities measured at fair value at September 30, 2009, is as follows:
 
Assets and Liabilities Measured at Fair Value on a Recurring Basis
 
                                 
        Prices in Active
  Other
   
        Markets for
  Observable
  Unobservable
    At September 30
  Identical Assets
  Inputs
  Inputs
    2009   (Level 1)   (Level 2)   (Level 3)
    (Millions of dollars)
 
Marketable Securities
    $121       $121       $—       $—  
Derivatives
    103       10       93        
                                 
Total Recurring Assets at Fair Value
    $224       $131       $93       $—  
                                 
Derivatives
    $131       $  54       $77       $—  
                                 
Total Recurring Liabilities at Fair Value
    $131       $  54       $77       $—  
                                 
 
Marketable Securities The company calculates fair value for its marketable securities based on quoted market prices for identical assets and liabilities. The fair values reflect the cash that would have been received if the instruments were sold at September 30, 2009. Marketable securities had average maturities of less than one year.
 
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 amounts to the Consolidated Statement of Income. For derivatives with identical or similar provisions as contracts that are publicly traded on a regular basis, the company uses the market values of the publicly traded instruments as an input for fair-value calculations.
 
The company’s derivative instruments principally include crude oil, natural gas and refined-product futures, swaps, options and forward contracts. Derivatives classified as Level 1 include futures, swaps and options contracts traded in active markets such as the New York Mercantile Exchange.


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
Derivatives classified as Level 2 include swaps, options, and forward 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. The company obtains multiple sources of pricing information for the Level 2 instruments. Since this pricing information is generated from observable market data, it has historically been very consistent. The company does not materially adjust this information. The company incorporates internal review, evaluation and assessment procedures, including a comparison of Level 2 fair values derived from the company’s internally developed forward curves (on a sample basis) with the pricing information to document reasonable, logical and supportable fair-value determinations and proper level of classification.
 
The fair-value hierarchy for nonrecurring assets and liabilities measured at fair value at September 30, 2009, is as follows:
 
Assets and Liabilities Measured at Fair Value on a Non-Recurring Basis
 
                                                 
        Prices in Active
  Other
      Loss (Before Tax)
  Loss (Before Tax)
        Markets for
  Observable
  Unobservable
  Three Months Ended
  Nine Months Ended
    At September 30
  Identical Assets
  Inputs
  Inputs
  September 30,
  September 30,
    2009   (Level 1)   (Level 2)   (Level 3)   2009   2009
    (Millions of dollars)
 
Properties, plant and equipment, net (held and used)
    $89       $—       $—       $89       $93       $358  
Properties, plant and equipment, net (held for sale)
                                  92  
                                                 
Total Nonrecurring Assets at Fair Value
    $89       $—       $—       $89       $93       $450  
                                                 
 
Impairments of “Properties, plant and equipment” In accordance with the accounting standard for the impairment or disposal of long-lived assets, long-lived assets “held and used” with a carrying amount of $182 million were written down to a fair value of $89 million, resulting in a before-tax loss of $93 million. The fair values were determined from internal cash-flow models, using discount rates consistent with those used by the company to evaluate cash flows of other assets of a similar nature.
 
Assets and Liabilities not Required to be Measured at Fair Value Accounting standards for interim disclosures about fair value of financial instruments require certain fair-value disclosures to be presented in both interim and annual reports. The company holds cash equivalents in U.S. and non-U.S. portfolios. The instruments held are primarily time deposits and money market funds. Cash equivalents had carrying/fair values of $5.7 billion and $7.1 billion at September 30, 2009 and December 31, 2008, respectively, and average maturities under 90 days. The balance at September 30, 2009, includes $214 million of investments for restricted funds related to an international upstream development project and a U.S. downstream construction project. The amounts are included in “Deferred charges and other assets” on the Consolidated Balance Sheet. Long-term debt of $5.8 billion and $1.2 billion had estimated fair values of $6.4 billion and $1.4 billion at September 30, 2009 and December 31, 2008, respectively.
 
Fair values of other financial instruments at September 30, 2009, were not material.
 
Note 13.  Derivative Instruments and Hedging Activities
 
Accounting standards for the disclosure of derivative instruments and hedging activities require a discussion of how and why the company uses derivative instruments, how derivative instruments and related hedged items are accounted for, and how derivative instruments affect the company’s financial position, financial performance and cash flows.
 
The company’s derivative instruments principally include crude-oil, natural-gas and refined-product futures, swaps, options and forward contracts. None of the company’s derivative instruments is designated as a hedging instrument, although certain of the company’s affiliates make such designation. The company’s derivatives are not material to


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
the company’s financial position, financial performance or cash flows. 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.
 
Derivative instruments measured at fair value at September 30, 2009, and their classification on the Consolidated Balance Sheet and Consolidated Statement of Income are presented in the following tables:
 
Consolidated Balance Sheet:
Fair Value of Derivatives not Designated as Hedging Instruments
 
                                         
        Asset Derivatives —
      Liability Derivatives —
        Fair Value       Fair Value
                (Millions of Dollars)
       
         Type of
  Balance Sheet
  At September 30
  At December 31
  Balance Sheet
  At September 30
  At December 31
Derivative Contract
  Classification   2009   2008   Classification   2009   2008
 
Foreign Exchange
  Accounts and notes receivable, net     $  —       $    5     Accrued liabilities     $  —       $  89  
Commodity
  Accounts and notes receivable, net     94       764     Accounts payable     115       344  
Commodity
  Long-term
receivables, net
    9       30     Deferred credits and other noncurrent obligations     16       83  
                                         
          $103       $799           $131       $516  
                                         
 
Consolidated Statement of Income:
The Effect of Derivatives not Designated as Hedging Instruments
 
                                     
        Gain/(Loss)
    Gain/(Loss)
 
        Three Months Ended
    Nine Months Ended
 
        September 30     September 30  
        2009     2008     2009     2008  
         Type of
               
Derivative Contract
  Statement of Income Classification   (Millions of dollars)     (Millions of dollars)  
 
Foreign Exchange
  Other income   $     $ (89 )   $ 85     $ (91 )
Commodity
  Sales and other operating revenues     31       568       (63 )     131  
Commodity
  Purchased crude oil and products     (18 )     555       (295 )     (182 )
Commodity
  Other income     5       1       1       (5 )
                                     
        $ 18     $ 1,035     $ (272 )   $ (147 )
                                     
 
Note 14.  Assets Held For Sale
 
At September 30, 2009, the company classified $316 million of net properties, plant and equipment as “Assets held for sale” on the Consolidated Balance Sheet. These assets are associated with upstream, downstream and mining businesses and are expected to be sold before the end of 2009.
 
Note 15.  New Accounting Standards
 
In June 2009, the FASB issued an accounting standard for transfers of financial assets, which will become effective for the company on January 1, 2010. The standard changes how companies account for transfers of financial assets and eliminates the concept of qualifying special-purpose entities. Adoption of the guidance is not expected to have an impact on the company’s results of operations, financial position or liquidity.
 
In June 2009, the FASB issued an accounting standard for variable-interest entities (VIEs), which will become effective for the company January 1, 2010. The standard requires the enterprise to qualitatively assess if it is the


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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
 
primary beneficiary of the VIE and, if so, the VIE must be consolidated. Adoption of the standard is not expected to have a material impact on the company’s results of operations, financial position or liquidity.
 
In June 2009, the FASB issued its Accounting Standards Codification (ASC) system, which became effective for the company in the quarter ending September 30, 2009. This standard established the ASC as the single authoritative source of U.S. generally accepted accounting principles (GAAP) and superseded existing literature of the FASB, Emerging Issues Task Force, American Institute of CPAs and other sources. The ASC did not change GAAP but organized the literature into about 90 accounting Topics. Adoption of the ASC did not affect the company’s accounting.


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Item 2.  Management’s Discussion and Analysis of Financial Condition and Results of Operations
 
Third Quarter 2009 Compared with Third Quarter 2008
And Nine Months 2009 Compared with Nine Months 2008
 
Key Financial Results
 
Earnings by Business Segment
 
                                 
    Three Months Ended
    Nine Months Ended
 
    September 30     September 30  
    2009     2008     2009     2008  
    (Millions of dollars)  
 
Upstream — Exploration and Production
                               
United States
  $ 878     $ 2,187     $ 1,172     $ 5,977  
International
    2,762       3,995       5,256       12,581  
                                 
Total Upstream
    3,640       6,182       6,428       18,558  
                                 
Downstream — Refining, Marketing and Transportation
                               
United States
    34       1,014       72       336  
International
    160       817       1,106       1,013  
                                 
Total Downstream
    194       1,831       1,178       1,349  
                                 
Chemicals
    164       70       311       154  
                                 
Total Segment Earnings
    3,998       8,083       7,917       20,061  
All Other
    (167 )     (190 )     (504 )     (1,025 )
                                 
Net Income Attributable to Chevron Corporation(1)(2)
  $ 3,831     $ 7,893     $ 7,413     $ 19,036  
                                 
                               
(1) Includes foreign currency effects
  $ (170 )   $ 303     $ (677 )   $ 384  
(2) Also referred to as “earnings” in the discussions that follow.
               
 
Net income attributable to Chevron Corporation for the third quarter 2009 was $3.83 billion ($1.92 per share — diluted), compared with $7.89 billion ($3.85 per share — diluted) in the corresponding 2008 period. Net income attributable to Chevron Corporation for the first nine months of 2009 was $7.41 billion ($3.71 per share — diluted), versus $19.04 billion ($9.23 per share — diluted) in the 2008 first nine months.
 
Upstream earnings in the third quarter 2009 were $3.64 billion, compared with $6.18 billion in the 2008 quarter. Earnings for the first nine months of 2009 were $6.43 billion, versus $18.56 billion a year earlier. The decrease between both comparative periods was due mainly to lower prices for crude oil and natural gas.
 
Downstream earnings were $194 million in the third quarter 2009, compared with $1.83 billion in the year-earlier period. Earnings for the first nine months of 2009 were $1.18 billion, versus $1.35 billion in the corresponding 2008 period. Earnings for the first nine months of 2009 included $540 million of gains in the first half of the year on sales of marketing businesses outside the United States.
 
Chemicals earned $164 million and $311 million for the third quarter and the first nine months of 2009, respectively. Comparative amounts in 2008 were $70 million and $154 million. Earnings increased on lower utility and manufacturing costs in Chevron Phillips Chemical Company LLC and higher margins on the sale of lubricant and fuel additives by Chevron’s Oronite subsidiary.
 
Refer to pages 27 through 30 for additional discussion of results by business segment and “All Other” activities for the third quarter and first nine months of 2009 versus the same periods in 2008.


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Business Environment and Outlook
 
Chevron is a global energy company with significant business activities in the following countries: Angola, Argentina, Australia, Azerbaijan, Bangladesh, Brazil, Cambodia, Canada, Chad, China, Colombia, Democratic Republic of the Congo, Denmark, Indonesia, Kazakhstan, Myanmar, the Netherlands, Nigeria, Norway, the Partitioned Neutral Zone between Saudi Arabia and Kuwait, the Philippines, Republic of the Congo, Singapore, South Africa, South Korea, Thailand, Trinidad and Tobago, the United Kingdom, the United States, Venezuela, and Vietnam.
 
Earnings of the company 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.
 
In recent years and through most of 2008, Chevron and the oil and gas industry at large experienced an increase in certain costs that exceeded the general trend of inflation in many areas of the world. This increase in costs affected the company’s operating expenses and capital programs for all business segments, but particularly for upstream. These cost pressures began to soften somewhat in late 2008, and the general trend has continued into 2009. The company is actively managing its schedule of work, contracting, procurement and supply-chain activities to capture the value associated with this decline in costs. (Refer to the “Upstream” section below for a discussion of the trend in crude-oil prices.)
 
The company’s operations, especially 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 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. From time to time, certain governments have sought to renegotiate contracts or impose additional costs on the company. 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 expected to provide sufficient long-term value or to acquire assets or operations complementary to its asset base to help augment the company’s growth. Refer to the “Results of Operations” section beginning on page 27 for discussions of net gains on asset sales during the first nine months of 2009. Asset dispositions and restructurings may also occur in future periods and could result in significant gains or losses.
 
The company continues to closely monitor developments in the financial and credit markets, the level of worldwide economic activity and the implications to the company of movements in prices for crude oil and natural gas. Management is taking these developments into account in the conduct of daily operations and for business planning. The company remains confident of its underlying financial strength to deal with potential problems presented in this environment. (Refer also to discussion of the company’s liquidity and capital resources on page 34.)
 
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,


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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. 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 and changes in tax laws and regulations.
 
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 commodity prices and 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. Capital and exploratory expenditures and operating expenses also can be affected by damage to production facilities caused by severe weather or civil unrest. The chart below shows the trend in benchmark prices for West Texas Intermediate (WTI) crude oil and U.S. Henry Hub natural gas. During 2008, industry price levels for WTI averaged $100 per barrel. The WTI price peaked at $147 in July 2008 and fell sharply to $45 at the end of the year. The WTI price in the first nine months of 2009 averaged $57 and ended October at about $77. The decline in prices from July 2008 is largely associated with a weakening in global economic conditions and a reduction in the demand for crude oil and petroleum products. In an October 2009 report, the International Energy Agency (IEA) predicted global demand for crude oil in 2009 would decline 1.9 percent from the 2008 level of consumption. Such a contraction in demand would be the most severe since the early 1980s. In the same report, IEA projected 2010 demand will increase 1.7 percent from expected consumption for the full-year 2009.
 
     
(LINE GRAPH)   A differential in crude-oil prices exists between high-quality (high-gravity, low sulfur) crudes and those of lower-quality (low-gravity, high sulfur). The amount of the differential in any period is associated with the supply of heavy crude available versus the demand that is a function of 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 differential has narrowed significantly over
the past year as production curtailments in the industry mainly have been of lower-quality crudes. 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 33 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. Prices at Henry Hub averaged about $3.50 per thousand cubic feet (MCF) in the first nine months of 2009, compared with about $10 for the first nine months of 2008 and almost $9 for the full-year 2008. At the end of October 2009, the Henry Hub spot price was about $4.12 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 level of inventory in underground storage relative to customer demand. The lower U.S. price levels in 2009 are also associated with weaker demand as a result of the economic slowdown. In an October 2009 report, the U.S. Energy Information Administration (EIA) forecasted 2009 natural-gas demand in the United States would drop 2.0 percent from 2008 consumption levels and 2010 demand is expected to be about the same as in 2009.
 
Certain other regions of the world in which the company operates have different supply, demand and regulatory circumstances, which until recently resulted in significantly lower average sales prices than in the United States for


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the company’s production of natural gas. As a result of the U.S. natural gas supply-and-demand conditions in the first nine months of 2009, the company’s U.S. and international realizations were about the same. (Refer to page 33 for the company’s average natural gas realizations for the U.S. and international regions.)
 
For the first nine months of 2009, the company’s worldwide net oil-equivalent production averaged 2.68 million barrels per day. During the first half of 2009, the company’s net oil production was curtailed by an average of about 40,000 barrels per day due to quotas imposed by OPEC. Curtailments by OPEC did not constrain the company’s production in the third quarter 2009. About one-fifth of the company’s net oil-equivalent production in the first nine months occurred in the OPEC-member countries of Angola, Nigeria and Venezuela and in the Partitioned Neutral Zone between Saudi Arabia and Kuwait.
 
The company estimates that production for the full-year 2009 will be at about the same level as in the first nine months. This estimate is subject to many factors and uncertainties, including additional quotas that may be imposed by OPEC, price effects on production volumes calculated under cost-recovery and variable-royalty provisions of certain contracts, changes in fiscal terms or restrictions on the scope of company operations, delays in project startups, fluctuations in demand for natural gas in various markets, weather conditions that may shut in production, civil unrest, changing geopolitics, or other disruptions to operations. The outlook for future production levels also is 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. Investments in upstream projects generally begin well in advance of the start of the associated crude-oil and natural-gas production. A significant majority of Chevron’s upstream investment is currently being made outside the United States.
 
Refer to the Results of Operations on pages 27 through 28 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, cost of materials and services, 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, and the effectiveness of the crude-oil and product-supply functions. 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, southern Africa and the United Kingdom. Chevron operates or has significant ownership interests in refineries in each of these areas, except Latin America. As part of its downstream strategy to focus on areas of market strength, the company completed sales of marketing businesses during the first nine months of 2009 in Brazil and certain countries in Africa.
 
The company’s refining and marketing margins in the first nine months of 2009 were generally weak, as demand for refined products in most areas was dampened by the economic slowdown, resulting in refined-product supplies that were plentiful in most areas.
 
Refer to the Results of Operations on pages 29 through 30 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 30 for additional discussion of chemical earnings.


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Operating Developments
 
Recent milestones for upstream projects were achieved in:
 
Australia
 
•  Final investment decision to proceed with the development of the Gorgon LNG project, in which Chevron will have an approximate 47 percent-owned and operated interest.
 
•  Discoveries of natural gas in the Carnarvon Basin off the northwest coast in the 67 percent-owned Block WA-205-P, the 50 percent-owned Block WA-365-P and the 50 percent-owned Block WA-374-P, all Chevron-operated.
 
•  Agreements signed with two companies to join Chevron’s planned Wheatstone LNG project as combined 25 percent owners and suppliers of natural gas for the project’s first two LNG trains.
 
Angola
 
•  Start-up of the 31 percent-owned and operated deepwater Tombua-Landana project in Block 14, which is expected to reach maximum total production of approximately 100,000 barrels of crude oil per day in 2011.
 
•  Discovery of crude oil and natural gas offshore in the 39 percent-owned and operated Block 0 concession, extending a trend of earlier discoveries in the Greater Vanza Longui Area.
 
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 4 beginning on page 9 for a discussion of the company’s “reportable segments,” as defined under the accounting standards for segment reporting.)
 
Upstream
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
U.S. Upstream Earnings
    $878       $2,187       $1,172       $5,977  
                                 
 
U.S. upstream earnings of $878 million in the third quarter of 2009 decreased about $1.3 billion from the same period last year. Lower prices for crude oil and natural gas reduced earnings by about $1.9 billion between periods, while gains on asset sales were approximately $300 million lower. These effects were partly offset by a benefit to income of about $800 million due to an increase in net oil-equivalent production. An additional benefit to income of approximately $500 million from lower operating expenses was substantially offset by higher depreciation and other items. The benefit from lower operating expenses was largely associated with charges recorded in the third quarter 2008 due to hurricane damages.
 
Earnings for the first nine months of 2009 were approximately $1.2 billion, down about $4.8 billion from the corresponding period in 2008. Lower prices for crude oil and natural gas reduced earnings by about $5.3 billion between periods, while an increase in net oil- equivalent production benefited income by about $600 million. Other items of lesser significance were largely offsetting between periods.
 
The average realization per barrel for crude oil and natural gas liquids in the third quarter of 2009 was approximately $60, compared with $107 a year earlier. For the nine-month periods, average realizations were about $50 and $101 for 2009 and 2008, respectively. The average natural-gas realization in the third quarter 2009 was $3.28 per thousand cubic feet, compared with $8.64 in the year-ago period. The nine-month realizations were $3.56 in 2009 and $8.66 in 2008.


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Net oil-equivalent production of 745,000 barrels per day in the third quarter 2009 was up 98,000 barrels per day, or 15 percent, from the corresponding period in 2008. Nine-month 2009 production was 705,000 barrels per day, up 17,000 from the nine-month period of 2008. The increase in production was primarily associated with start-up of the Blind Faith Field in late 2008 and the Tahiti Field in second quarter 2009. The net liquids component of oil-equivalent production was 509,000 barrels per day and 472,000 barrels per day for the third quarter and nine months of 2009, respectively. Those volumes were about 24 percent and 10 percent higher than the corresponding 2008 periods. Net natural gas production was about 1.4 billion cubic feet per day for both the third quarter and nine months of 2009, down about 1 percent and 10 percent from the comparative 2008 periods.
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
International Upstream Earnings*
    $2,762       $3,995       $5,256       $12,581  
                                 
                               
* Includes foreign currency effects
    $    (81 )     $   316       $  (524 )     $     229  
 
International upstream earnings of approximately $2.8 billion in the third quarter 2009 decreased about $1.2 billion from the corresponding period in 2008. Lower prices for crude oil and natural gas reduced earnings by about $2.3 billion between periods. Partially offsetting this effect was an approximate $1 billion benefit due to an increase in sales volumes of crude oil. Another benefit of $400 million associated with third-quarter 2009 asset sales and tax items related to the Gorgon project in Australia was substantially offset by an unfavorable swing in foreign-currency effects.
 
Earnings for the first nine months of 2009 were $5.3 billion, down $7.3 billion from the same period in 2008. Lower prices for crude oil and natural gas decreased earnings by $8.2 billion, while foreign-currency effects and higher expenses (operating, depreciation and exploration) reduced income by a total of $1.5 billion between periods. Partially offsetting these items were benefits of $2.1 billion resulting from an increase in sales volumes of crude oil and $400 million related to the Gorgon project (discussed above).
 
The average realization per barrel of crude oil and natural gas liquids in the third quarter 2009 was about $62, compared with $103 in the corresponding 2008 period. For the 2009 nine-month period, the average realization was about $52 per barrel, down from $100 in 2008. The average natural-gas realization in the 2009 third quarter was $3.92 per thousand cubic feet, down from $5.37 in the third quarter last year. Between the nine-month periods, the average natural-gas realization decreased to $3.95 from $5.21.
 
Net oil-equivalent production, including volumes from oil sands in Canada, was about 1.96 million barrels per day in the third quarter 2009, up about 161,000 barrels per day from the year-ago period. Included in the increase was about 220,000 barrels per day of production associated with two projects — Agbami in Nigeria, which commenced operations in the third quarter of last year, and the expansion at Tengiz in Kazakhstan. Partially offsetting this increase was production offline in the 2009 third quarter due to civil unrest in Nigeria.
 
Net oil-equivalent production, including volumes from oil sands in Canada, for the nine-months of 2009 was 1.97 million barrels per day, up 135,000 barrels per day from the 2008 period. Included in the increase was about 120,000 barrels per day from Agbami and approximately 70,000 barrels per day from Tengiz. Factors other than normal field declines that partially offset these increases included lower production in Thailand and the effect of civil unrest in Nigeria.
 
The net liquids component of oil-equivalent production, including volumes from oil sands in Canada, was 1.38 million barrels per day in both the third quarter and the nine-month period of 2009, an increase of 15 and 12 percent for the respective periods. Net natural-gas production of 3.48 billion cubic feet per day in the third quarter 2009 and 3.57 billion cubic feet per day in the corresponding 2009 period decreased about 4 percent and 3 percent, respectively.


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Downstream
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
U.S. Downstream Earnings
    $34       $1,014       $72       $336  
                                 
 
U.S. downstream earned $34 million in the third quarter 2009, compared with $1.0 billion a year earlier. Substantially all of the decline was associated with weaker margins on the sale of gasoline and other refined products and the absence of gains recorded in the third quarter 2008 on commodity derivative instruments. A decline in operating expenses benefited income by about $100 million between periods.
 
Earnings for the first nine months of 2009 were $72 million, compared with $336 million in the same period of 2008. A decline in refined-product margins between periods was partially offset by a benefit of about $200 million from lower operating expenses.
 
Crude-oil inputs to the company’s refineries were 879,000 barrels per day in the third quarter 2009, down 43,000 barrels per day from a year earlier due primarily to the effects of a planned shutdown in this year’s third quarter at the refinery in Richmond, California. Inputs of 913,000 barrels per day for the nine months of 2009 increased about 4 percent from the corresponding 2008 period due mainly to less planned and unplanned refinery downtime.
 
Refined-product sales were 1.42 million barrels per day for both the quarterly and nine-month periods in 2009, essentially unchanged from the comparative periods in 2008. Branded gasoline sales volumes were 623,000 and 625,000 barrels per day for the third quarter and nine months in 2009, each representing an approximate 4 percent increase from the corresponding 2008 periods.
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
International Downstream Earnings*
    $160       $817       $1,106       $1,013  
                                 
                               
* Includes foreign currency effects
    $(97 )     $  63       $  (187 )     $  220  
 
International downstream earned $160 million in the third quarter 2009, compared with $817 million a year earlier. An approximate $800 million decline was associated with weaker margins on the sale of gasoline and other refined products and the absence of gains recorded in the third quarter 2008 on commodity derivative instruments. An unfavorable swing in foreign-currency effects totaled $160 million. A decline in operating expenses benefited income by about $300 million between periods.
 
Earnings for the first nine months of 2009 were about $1.1 billion, up less than $100 million from the corresponding 2008 period. An approximate $800 million decline between periods was associated with weaker margins on the sale of gasoline and other refined products and the absence of gains recorded in the first nine months of 2008 on commodity derivative instruments. An unfavorable swing in foreign-currency effects totaled about $400 million. More than offsetting these items were benefits of about $800 million from lower operating expenses and $540 million from gains on asset sales in Latin America and Africa. The lower operating expenses were associated mainly with transportation expenses and labor costs.
 
The company’s share of crude-oil inputs to refineries was 985,000 barrels per day in the 2009 third quarter, up 9,000 from the year-ago period. For the nine months of 2009, crude-oil inputs were 980,000 barrels per day, up 15,000 from the year-ago period. The increase for both comparative periods was attributable mainly to less planned and unplanned refinery downtime.
 
Refined-product sales volumes of 1.82 million barrels per day in the 2009 third quarter and 1.87 million barrels per day for the first nine months of 2009 were each about 9 percent lower than in the corresponding periods of 2008. The declines were due mainly to asset sales (discussed above). Excluding the impact of asset sales, refined-product


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sales were down 2 percent between quarters and 4 percent between the nine-month periods on reduced volumes of jet fuel and fuel oil.
 
Chemicals
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
Earnings*
    $164       $70       $311       $154  
                                 
                               
* Includes foreign currency effects
    $    1       $(5 )     $  14       $  (5 )
 
Chemical operations earned $164 million in the third quarter of 2009, compared with $70 million in the year-ago quarter. Nine-month earnings increased from $154 million in 2008 to $311 million in 2009. For both comparative periods, earnings increased at the 50 percent-owned Chevron Phillips Chemical Company LLC (CPChem) due to lower utility costs, the effect of which was partially offset by lower margins on the sale of commodity chemicals. For Chevron’s Oronite subsidiary, earnings in the third quarter and for the nine-month periods of 2009 increased from a year earlier on higher margins for the sale of lubricant and fuel additives, the effect of which more than offset the impact of lower sales volumes.
 
All Other
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
Net Charges*
    $(167 )     $(190 )     $(504 )     $(1,025 )
                                 
                               
* Includes foreign currency effects
    $     7       $  (71 )     $   20       $     (60 )
 
All Other consists of 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.
 
Net charges in the third quarter 2009 were $167 million, essentially unchanged from the year-ago period. For the nine months of 2009, net charges were $504 million, compared with $1.0 billion a year earlier. Net charges were lower in the 2009 nine-month period for environmental remediation at sites that previously had been closed or sold, corporate tax items and employee compensation and benefits.
 
Consolidated Statement of Income
 
Explanations of variations between periods for certain income statement categories are provided below:
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
        (Millions of dollars)    
 
Sales and other operating revenues
    $45,180       $76,192       $119,814       $221,813  
                                 
 
Sales and other operating revenues for the quarterly and nine-month periods decreased $31 billion and $102 billion, respectively, due mainly to lower prices for crude oil, natural gas and refined products.
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
Income from equity affiliates
    $1,072       $1,673       $2,418       $4,480  
                                 


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Income from equity affiliates decreased between the quarterly and nine-month periods due mainly to lower upstream-related earnings from Tengizchevroil in Kazakhstan and Petropiar in Venezuela caused by lower prices for crude oil. Downstream-related earnings were also lower between the comparative periods due primarily to an unfavorable swing in foreign-exchange effects at GS Caltex in South Korea.
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
Other income
    $373       $1,002       $728       $1,509  
                                 
 
Other income for the quarterly period in 2009 decreased mainly due to lower gains on asset sales, foreign-exchange losses associated with weakening of the U.S. dollar and lower interest income. The decline for the nine-month period was primarily the result of an unfavorable swing in foreign-exchange effects and lower interest income. These items were partially offset by increased gains on asset sales.
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
Purchased crude oil and products
    $26,969       $49,238       $71,047       $147,822  
                                 
 
Purchases decreased $22 billion and $77 billion in the quarterly and nine-month periods due mainly to lower prices for crude oil, natural gas and refined products.
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
Operating, selling, general and administrative expenses
    $5,580       $6,954       $16,155       $19,643  
                                 
 
Operating, selling, general and administrative expenses decreased approximately $1.4 billion between quarters and $3.5 billion between the nine-month periods. Lower expenses related to materials, services, equipment rentals, contract labor, fuel and shipping charters and other transportation accounted for approximately $500 million and $1.9 billion of the decline between the quarterly and nine-month periods, respectively. In addition, hurricane-related charges net of insurance recoveries declined $800 million between both comparative periods.
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
Exploration expenses
    $242       $271       $1,061       $831  
                                 
 
The decline in exploration expenses between quarters was due to lower amounts for well write-offs. Exploration expenses in the nine month period in 2009 increased due to higher amounts for well write-offs and geological and geophysical costs.
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
Depreciation, depletion and amortization
    $2,988       $2,449       $8,954       $6,939  
                                 
 
The increase in both comparative periods was associated mainly with production start-ups for upstream projects in the United States and Africa and higher depreciation rates for certain other oil and gas producing fields.
 


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    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
    (Millions of dollars)
 
Taxes other than on income
    $4,644       $5,614       $13,008       $16,756  
                                 
 
Taxes other than on income decreased primarily due to lower import duties in the company’s U.K. downstream operations.
 
                                 
    Three Months Ended
  Nine Months Ended
    September 30   September 30
    2009   2008   2009   2008
        (Millions of dollars)    
 
Income tax expense
    $2,342       $6,416       $5,246       $16,681  
                                 
 
Effective income tax rates for the 2009 and 2008 third quarters were 38 percent and 45 percent, respectively. For the year-to-date periods, the effective tax rates were 41 and 47 percent, respectively.
 
The decline in the effective tax rates between the quarterly and nine-month periods was generally associated with the same factors. These factors included the effect in 2009 of relatively low tax rates on asset sales and deferred-tax benefits, both related to an international upstream project. In addition, a greater proportion of before-tax income was earned in 2009 by equity affiliates than in 2008. (Equity-affiliate income is reported as a single amount on an after-tax basis on the Consolidated Statement of Income.)

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Selected Operating Data
 
The following table presents a comparison of selected operating data:
 
Selected Operating Data(1)(2)
 
                                 
    Three Months Ended
    Nine Months Ended
 
    September 30     September 30  
    2009     2008     2009     2008  
 
U.S. Upstream
                               
Net crude-oil and natural-gas-liquids production (MBPD)
    509       409       472       428  
Net natural-gas production (MMCFPD)(3)
    1,420       1,431       1,398       1,561  
Net oil-equivalent production (MBOEPD)
    745       647       705       688  
Sales of natural gas (MMCFPD)
    5,832       7,142       5,974       7,591  
Sales of natural gas liquids (MBPD)
    161       155       158       156  
Revenue from net production
                               
Crude oil and natural gas liquids ($/Bbl.)
  $ 60.20     $ 107.22     $ 49.53     $ 100.73  
Natural gas ($/MCF)
  $ 3.28     $ 8.64     $ 3.56     $ 8.66  
International Upstream
                               
Net crude-oil and natural-gas-liquids production (MBPD)
    1,350       1,167       1,352       1,201  
Net natural-gas production (MMCFPD)(3)
    3,475       3,618       3,570       3,669  
Net oil-equivalent production (MBOEPD)(4)
    1,957       1,796       1,973       1,838  
Sales of natural gas (MMCFPD)
    4,035       4,224       4,084       4,201  
Sales of natural gas liquids (MBPD)
    104       105       110       122  
Revenue from liftings
                               
Crude oil and natural gas liquids ($/Bbl.)
  $ 61.90     $ 102.73     $ 51.50     $ 99.93  
Natural gas ($/MCF)
  $ 3.92     $ 5.37     $ 3.95     $ 5.21  
U.S. and International Upstream
                               
Total net oil-equivalent production, including volumes from oil sands (MBOEPD)(3)(4)
    2,702       2,443       2,678       2,526  
U.S. Downstream
                               
Gasoline sales (MBPD)(5)
    737       706       725       694  
Sales of other refined products (MBPD)
    679       716       695       719  
                                 
Total
    1,416       1,422       1,420       1,413  
Refinery input (MBPD)
    879       922       913       878  
International Downstream
                               
Gasoline sales (MBPD)(5)
    435       500       458       505  
Sales of other refined products (MBPD)
    868       1,007       905       1,034  
Share of affiliate sales (MBPD)
    519       501       504       503  
                                 
Total
    1,822       2,008       1,867       2,042  
Refinery input (MBPD)
    985       976       980       965  
                                 
                               
(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
    56       69       57       77  
International(6)
    455       434       467       447  
(4) Includes production from oil sands — net (MBPD):
    27       26       26       26  
(5) Includes branded and unbranded gasoline.
                               
(6) 2008 conformed to 2009 presentation.
                               


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Liquidity and Capital Resources
 
Cash, cash equivalents and marketable securities totaled approximately $7.7 billion at September 30, 2009, down $1.9 billion from year-end 2008. Cash provided by operating activities in the first nine months of 2009 was $12.4 billion, compared with $24.4 billion in the year-ago period. The net cash provided by operating activities in the 2009 period was slightly higher than the $11.9 billion of cash used for investing activities, which included $2 billion for the extension of an upstream concession. (Refer also to the discussion of the company’s capital and exploratory expenditures on page 35.)
 
Dividends The company paid dividends of $3.9 billion to common stockholders during the first nine months of 2009. In October 2009, the company declared a quarterly dividend of 68 cents per common share payable in December 2009.
 
Debt and Capital Lease and Noncontrolling Interest Obligations Chevron’s total debt and capital lease obligations were $10.5 billion at September 30, 2009, up from $8.9 billion at December 31, 2008. The company also had noncontrolling interest obligations of $576 million at September 30, 2009.
 
The $1.6 billion increase in total debt and capital lease obligations during the first nine months of 2009 included the net effect of a $5 billion public bond issuance, $350 million issuance of a tax-exempt Gulf Opportunity Zone bond, $3.2 billion decrease in commercial paper, and $400 million payment of principal for Texaco Capital Inc. bonds that matured in January. 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 $4.5 billion at September 30, 2009, and $7.8 billion at December 31, 2008. Of these amounts, $4.3 billion and $5.0 billion were reclassified to long-term at the end of the respective periods. At September 30, 2009, 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 September 30, 2009, the company had $5.1 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 September 30, 2009. In addition, the company has an automatic shelf registration statement that expires in March 2010 for an unspecified amount of nonconvertible debt securities issued or guaranteed by the company.
 
The company has outstanding public bonds issued by Chevron Corporation, Chevron Corporation Profit Sharing/Savings Plan Trust Fund, Texaco Capital Inc. and Union Oil Company of California. All of these securities are the obligations of, or 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 did not acquire any shares during the first nine months of 2009 and does not plan to acquire any shares in the 2009 fourth quarter. From the inception of the program, the company has acquired 119 million shares at a cost of $10.1 billion.


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Current Ratio — current assets divided by current liabilities. The current ratio was 1.4 at September 30, 2009, and 1.1 at December 31, 2008. The current ratio is adversely affected by the valuation of Chevron’s inventories on a LIFO basis. At September 30, 2009, the book value of inventory was significantly lower than replacement cost. The company does not consider its inventory valuation methodology to affect liquidity.
 
Debt Ratio — total debt as a percentage of total debt plus Chevron Corporation stockholders’ equity. This ratio was 10.4 percent at September 30, 2009, and 9.3 percent at year-end 2008.
 
Pension Obligations At the end of 2008, the company estimated it would contribute $800 million to employee pension plans during 2009 (composed of $550 million for the U.S. plans and $250 million for the international plans). Through September 30, 2009, a total of $860 million was contributed (including $741 million to the U.S. plans). Total contributions for the full year are currently estimated at $1 billion ($750 million for the U.S. plans and $250 million for the international plans). Actual contribution amounts are dependent upon investment returns, changes in pension obligations, regulatory environments and other economic factors. Additional funding may ultimately be required if investment returns are insufficient to offset increases in plan obligations.
 
Capital and Exploratory Expenditures Total expenditures, including the company’s share of spending by affiliates, were $16.0 billion in the first nine months of 2009, compared with $15.8 billion in the corresponding 2008 period. The amounts included the company’s share of equity-affiliate expenditures of about $900 million and $1.6 billion in the 2009 and 2008 periods, respectively. Outlays in the 2009 period included $2 billion for the extension of an upstream concession. Expenditures for upstream projects in the first nine months of 2009 were about $12.5 billion, representing 78 percent of the companywide total.
 
Capital and Exploratory Expenditures by Major Operating Area
 
                                 
    Three Months Ended
    Nine Months Ended
 
    September 30     September 30  
    2009     2008     2009     2008  
 
United States
                               
Upstream
  $ 662     $ 1,296     $ 2,474     $ 3,986  
Downstream
    446       497       1,369       1,397  
Chemicals
    57       195       131       322  
All Other
    100       153       256       418  
                                 
Total United States
    1,265       2,141       4,230       6,123  
                                 
International
                               
Upstream
    2,698       2,938       10,070       8,661  
Downstream
    610       395       1,653       949  
Chemicals
    23       18       57       40  
All Other
          1       1       4  
                                 
Total International
    3,331       3,352       11,781       9,654  
                                 
Worldwide
  $ 4,596     $ 5,493     $ 16,011     $ 15,777  
                                 
 
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. Chevron is a party to 50 pending lawsuits and claims, the majority of which involve numerous other petroleum marketers and refiners. Resolution of these lawsuits and claims may ultimately require the company to correct or ameliorate the alleged effects on the environment of prior release of MTBE by the company or other parties. Additional lawsuits and claims related to the use of MTBE, including personal-injury claims, may be filed in the future. The company’s ultimate exposure related to pending lawsuits and claims is not 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.


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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, health care systems, and additional infrastructure for Petroecuador. The engineer’s report also asserted 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 submitted a rebuttal to the report in which it asked the court to strike the report in its entirety. In November 2008, the engineer revised the report and, without additional evidence, recommended an increase in the financial compensation for purported damages to a total of $18.9 billion and an increase in the assessment for purported unjust enrichment to a total of $8.4 billion. Chevron submitted a rebuttal to the revised report, which the court dismissed. In September 2009, following the disclosure by Chevron of evidence that the judge participated in meetings in which businesspeople and individuals holding themselves out as government officials discussed the case and its likely outcome, the judge presiding over the case petitioned to be recused. In late September 2009, the judge was recused, and in October 2009, the full chamber of the provincial court affirmed the recusal, resulting in the appointment of a new judge. Chevron filed motions to annul all of the rulings made by the prior judge, but the new judge denied these motions. The court has completed most of the procedural aspects of the case and could render a judgment at any time. Chevron will continue a vigorous defense of any attempted imposition of liability.
 
In the event of an adverse judgment, Chevron would expect to pursue its appeals and vigorously defend against enforcement of any such judgment; therefore, the ultimate outcome — and any financial effect on Chevron — remains uncertain. Management does not believe an estimate of a reasonably possible loss (or a range of loss) can be made in this case. Due to the defects associated with the engineer’s report, management does not believe the report 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).
 
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


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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 September 2009, 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 had to be asserted by February 2009 for Equilon indemnities and must be asserted no later than February 2012 for Motiva indemnities. Under the terms of these indemnities, there is no maximum limit on the amount of potential future payments. In February 2009, Shell delivered a letter to the company purporting to preserve unmatured claims for certain Equilon indemnities. The letter itself provides no estimate of the ultimate claim amount, and management does not believe the letter or any other information provides a basis to estimate the amount, if any, of a range of loss or potential range of loss with respect to the Equilon or the Motiva 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 September 30, 2009.
 
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


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have, any significant impact on the company’s competitive position relative to other U.S. or international petroleum or chemical companies.
 
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 derivative activities.
 
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.
 
Noncontrolling Interests The company has commitments of $576 million related to noncontrolling interests in subsidiary companies.
 
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 September 30, 2009. For Chevron’s major tax jurisdictions, the latest years for which income tax examinations had been finalized were as follows: United States — 2005, 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.
 
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
 
In June 2009, the FASB issued an accounting standard for transfers of financial assets, which will become effective for the company on January 1, 2010. The standard changes how companies account for transfers of financial assets and eliminates the concept of qualifying special-purpose entities. Adoption of the guidance is not expected to have an impact on the company’s results of operations, financial position or liquidity.
 
In June 2009, the FASB issued an accounting standard for variable-interest entities (VIEs), which will become effective for the company January 1, 2010. The standard requires the enterprise to qualitatively assess if it is the primary beneficiary of the VIE and, if so, the VIE must be consolidated. Adoption of the standard is not expected to have a material impact on the company’s results of operations, financial position or liquidity.
 
In June 2009, the FASB issued its Accounting Standards Codification (ASC) system, which became effective for the company in the quarter ending September 30, 2009. This standard established the ASC as the single authoritative source of U.S. generally accepted accounting principles (GAAP) and superseded existing literature of the FASB, Emerging Issues Task Force, American Institute of CPAs and other sources. The ASC did not change GAAP but organized the literature into about 90 accounting Topics. Adoption of the ASC did not affect the company’s accounting.


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Item 3.  Quantitative and Qualitative Disclosures About Market Risk
 
Information about market risks for the three months ended September 30, 2009, does not differ materially from that discussed under Item 7A of Chevron’s 2008 Annual Report on Form 10-K.
 
Item 4.  Controls and Procedures
 
(a) Evaluation of disclosure controls and procedures
 
The company’s management has evaluated, with the participation of the Chief Executive Officer and Chief Financial Officer, the effectiveness of the company’s 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 September 30, 2009.
 
(b) Changes in internal control over financial reporting
 
During the quarter ended September 30, 2009, 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
 
In July 2009, the Hawaii Department of Health (“DOH”) alleged that Chevron is obligated to pay stipulated civil penalties exceeding $100,000 in conjunction with commitments the company undertook to install and operate certain air pollution abatement equipment at its Hawaii Refinery pursuant to Clean Air Act settlement with the United States Environmental Protection Agency and DOH. The company has disputed many of the allegations.
 
In October 2009, Chevron and SFO Fuel entered into a settlement with the United States Environmental Protection Agency regarding alleged violations of the Clean Water Act Spill Prevention Control and Countermeasure (“SPCC”) regulations. The alleged violations relate to spill containment structures at a SFO Fuel bulk jet fuel terminal located at San Francisco International Airport. As part of the settlement, Chevron and SFO Fuel will pay a civil penalty of $177,500.
 
Item 1A.  Risk Factors
 
Chevron is a major fully integrated petroleum company with a diversified business portfolio, a strong balance sheet, and a 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 September 30, 2009, does not differ materially from that set forth in Part I, Item 1A, of Chevron’s 2008 Annual Report on Form 10-K.


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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(2)
 
July 1-31, 2009
    200       66.50                
August 1-31, 2009
                         
September 1-30, 2009
    43       69.91                
                                 
Total
    243       67.11                
                                 
 
 
(1) Pertains to common shares repurchased during the three-month period ended September 30, 2009, 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 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 September 30, 2009.
 
(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 September 30, 2009, $10.1 billion had been expended to repurchase 118,996,749 shares since the common stock repurchase program began.


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Item 6.   Exhibits
 
     
Exhibit
   
Number
 
Description
 
(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
(101.INS)
  XBRL Instance Document
(101.SCH)
  XBRL Schema Document
(101.CAL)
  XBRL Calculation Linkbase Document
(101.LAB)
  XBRL Label Linkbase Document
(101.PRE)
  XBRL Presentation Linkbase Document
(101.DEF)
  XBRL Definition Linkbase Document
 
Attached as Exhibit 101 to this report are documents formatted in XBRL (Extensible Business Reporting Language). Users of this data are advised pursuant to Rule 406T of Regulation S-T that the interactive data file is deemed not filed or part of a registration statement or prospectus for purposes of section 11 or 12 of the Securities Act of 1933, is deemed not filed for purposes of section 18 of the Securities Exchange Act of 1934, and otherwise not subject to liability under these sections. The financial information contained in the XBRL-related documents is “unaudited” or “unreviewed.”


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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: November 5, 2009


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EXHIBIT INDEX
 
     
Exhibit
   
Number
 
Description
 
(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
(101.INS)*
  XBRL Instance Document
(101.SCH)*
  XBRL Schema Document
(101.CAL)*
  XBRL Calculation Linkbase Document
(101.LAB)*
  XBRL Label Linkbase Document
(101.PRE)*
  XBRL Presentation Linkbase Document
(101.DEF)*
  XBRL Definition Linkbase Document
 
Attached as Exhibit 101 to this report are documents formatted in XBRL (Extensible Business Reporting Language). Users of this data are advised pursuant to Rule 406T of Regulation S-T that the interactive data file is deemed not filed or part of a registration statement or prospectus for purposes of section 11 or 12 of the Securities Act of 1933, is deemed not filed for purposes of section 18 of the Securities Exchange Act of 1934, and otherwise not subject to liability under these sections. The financial information contained in the XBRL-related documents is “unaudited” or “unreviewed.”
 
 
* 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.


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