e10vq
UNITED STATES SECURITIES AND
EXCHANGE COMMISSION
Washington, D.C.
20549
Form 10-Q
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þ
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QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
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For the quarterly period ended
September 30,
2009
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or
|
o
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TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
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Commission file number 1-368-2
Chevron Corporation
(Exact name of registrant as
specified in its charter)
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Delaware
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94-0890210
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(State or other jurisdiction
of
incorporation or organization)
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|
(I.R.S. Employer
Identification Number)
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6001 Bollinger Canyon Road,
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94583-2324
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San Ramon, California
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(Zip Code)
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(Address of principal executive
offices)
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Registrants 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):
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Large accelerated
filer þ
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Accelerated
filer o
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Non-accelerated
filer o
(Do not check if a smaller reporting company)
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|
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
issuers classes of common stock, as of the latest
practicable date:
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Class
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Outstanding as of September 30, 2009
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Common stock, $.75 par value
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|
2,006,267,842
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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 Chevrons operations that are based on
managements 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 companys 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 companys 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 companys 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 companys
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
companys 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.
2
PART I.
FINANCIAL
INFORMATION
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|
Item 1.
|
Consolidated
Financial Statements
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Three Months Ended
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Nine Months Ended
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September 30
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September 30
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2009
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2008
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2009
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2008
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(Millions of dollars, except per-share amounts)
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Revenues and Other Income
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Sales and other operating revenues*
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$
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45,180
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$
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76,192
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$
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119,814
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$
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221,813
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Income from equity affiliates
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1,072
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1,673
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2,418
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4,480
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Other income
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373
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|
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|
1,002
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|
728
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1,509
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|
|
|
|
|
|
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|
|
|
|
|
|
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Total Revenues and Other Income
|
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46,625
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|
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78,867
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122,960
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227,802
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|
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Costs and Other Deductions
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|
|
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Purchased crude oil and products
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26,969
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|
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49,238
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|
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71,047
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147,822
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Operating expenses
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|
4,403
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|
|
|
5,676
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|
|
|
12,958
|
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15,379
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Selling, general and administrative expenses
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1,177
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|
|
|
1,278
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|
|
|
3,197
|
|
|
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4,264
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Exploration expenses
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|
|
242
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|
|
|
271
|
|
|
|
1,061
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|
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|
831
|
|
Depreciation, depletion and amortization
|
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|
2,988
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|
|
2,449
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|
|
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8,954
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|
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6,939
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Taxes other than on income*
|
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4,644
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5,614
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|
13,008
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16,756
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Interest and debt expense
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|
14
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28
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|
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Total Costs and Other Deductions
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40,437
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64,526
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110,253
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191,991
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Income Before Income Tax Expense
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6,188
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|
|
|
14,341
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|
|
|
12,707
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|
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35,811
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|
Income Tax Expense
|
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|
2,342
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|
|
|
6,416
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5,246
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|
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16,681
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|
|
|
|
|
|
|
|
|
|
|
|
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|
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Net Income
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|
3,846
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7,925
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7,461
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19,130
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Less: Net income attributable to noncontrolling interests
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15
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|
|
|
32
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|
|
48
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|
|
94
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Net Income Attributable to Chevron Corporation
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$
|
3,831
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$
|
7,893
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|
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$
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7,413
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$
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19,036
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Per Share of Common Stock:
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Net Income Attributable to Chevron Corporation
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Basic
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$
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1.92
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$
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3.88
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$
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3.72
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$
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9.29
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Diluted
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$
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1.92
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$
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3.85
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$
|
3.71
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$
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9.23
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Dividends
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$
|
0.68
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$
|
0.65
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$
|
1.98
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$
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1.88
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|
Weighted Average Number of Shares Outstanding (000s)
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Basic
|
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|
1,992,452
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2,032,433
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1,991,733
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2,049,812
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Diluted
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2,000,586
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2,044,616
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1,999,925
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|
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2,063,149
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* Includes excise, value-added and similar taxes:
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$
|
2,079
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|
|
$
|
2,577
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|
|
$
|
6,023
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|
|
$
|
7,766
|
|
See accompanying notes to consolidated financial statements.
3
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|
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|
|
|
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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:
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net gain (loss) arising during period
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|
8
|
|
|
|
(13
|
)
|
|
|
3
|
|
|
|
(5
|
)
|
Derivatives:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net derivatives gain (loss) on hedge transactions
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|
7
|
|
|
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126
|
|
|
|
(65
|
)
|
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|
74
|
|
Reclassification to net income of net realized (gain) loss
|
|
|
(9
|
)
|
|
|
4
|
|
|
|
(25
|
)
|
|
|
15
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|
Income taxes on derivatives transactions
|
|
|
1
|
|
|
|
(44
|
)
|
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|
31
|
|
|
|
(32
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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Total
|
|
|
(1
|
)
|
|
|
86
|
|
|
|
(59
|
)
|
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|
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
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)
|
|
|
(49
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)
|
|
|
(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.
4
|
|
|
|
|
|
|
|
|
|
|
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.
5
|
|
|
|
|
|
|
|
|
|
|
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.
6
NOTES TO
CONSOLIDATED FINANCIAL STATEMENTS
|
|
Note 1.
|
Interim
Financial Statements
|
The accompanying consolidated financial statements of Chevron
Corporation and its subsidiaries (the company) have not been
audited by an independent registered public accounting firm. In
the opinion of the companys 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 companys 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 companys
subsidiaries held by parties other than the parent are presented
separately from the parents 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. |
7
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 companys stock
repurchase program initiated in September 2007. No purchases
were made under the program in the 2009 period.
8
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
|
|
Companys 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 companys
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 companys chief operating decision
maker (CODM) (terms as defined in the accounting
standards). The CODM is the companys 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
companys CODM to discuss the segments 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.
9
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
The companys primary country of operation is the United
States of America, its country of domicile. Other components of
the companys 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
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10
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.
11
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
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
12
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 Chevrons 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 companys 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 Chevrons
international tanker fleet and is engaged in the marine
transportation of crude oil and refined petroleum products. Most
of CTCs shipping revenue is derived by providing
transportation services to other Chevron companies. Chevron
Corporation has fully and unconditionally guaranteed this
subsidiarys 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
|
|
13
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 CTCs ability to pay
dividends or make loans or advances at September 30, 2009.
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 companys 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
companys 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.
14
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 companys 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.
15
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
companys 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.
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 companys 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 Texpets 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
Texpets remediation was properly conducted and that the
remaining environmental damage reflects Petroecuadors
failure to timely fulfill its legal obligations and
Petroecuadors 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
engineers report also asserted that an additional
$8.3 billion could be assessed against Chevron for unjust
enrichment. The engineers report is not binding on the
court. Chevron also
16
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
believes that the engineers work was performed and his
report prepared in a manner contrary to law and in violation of
the courts 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
engineers 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 companys 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 companys 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
Texacos 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
17
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 companys 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 companys 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 companys 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 Chevrons
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.
18
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 companys 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.
19
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
companys 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 companys financial
position, financial performance and cash flows.
The companys derivative instruments principally include
crude-oil, natural-gas and refined-product futures, swaps,
options and forward contracts. None of the companys
derivative instruments is designated as a hedging instrument,
although certain of the companys affiliates make such
designation. The companys derivatives are not material to
20
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
the companys 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 companys 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
21
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 companys 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
companys accounting.
22
|
|
Item 2.
|
Managements
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
Chevrons 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.
23
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 companys 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 companys
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 companys 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 companys operations or
investments. Those developments have at times significantly
affected the companys 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 companys
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 companys 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
companys liquidity and capital resources on page 34.)
Comments related to earnings trends for the companys 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,
24
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 companys 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
companys 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 companys control. External factors include not only
the general level of inflation but also commodity prices and
prices charged by the industrys material- and
service-providers, which can be affected by the volatility of
the industrys 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.
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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
companys 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
25
the companys 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 companys
U.S. and international realizations were about the same.
(Refer to page 33 for the companys average natural
gas realizations for the U.S. and international regions.)
For the first nine months of 2009, the companys worldwide
net oil-equivalent production averaged 2.68 million barrels
per day. During the first half of 2009, the companys 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 companys
production in the third quarter 2009. About one-fifth of the
companys 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 Chevrons
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 companys 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 companys
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
companys shipping operations, which are driven by the
industrys demand for crude-oil and product tankers. Other
factors beyond the companys control include the general
level of inflation and energy costs to operate the
companys refinery and distribution network.
The companys 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 companys 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 companys 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.
26
Operating
Developments
Recent milestones for upstream projects were achieved in:
Australia
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|
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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.
|
|
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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.
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|
|
Agreements signed with two companies to join Chevrons
planned Wheatstone LNG project as combined 25 percent
owners and suppliers of natural gas for the projects 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 companys 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 companys
reportable segments, as defined under the accounting
standards for segment reporting.)
Upstream
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Three Months Ended
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Nine Months Ended
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September 30
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September 30
|
|
|
2009
|
|
2008
|
|
2009
|
|
2008
|
|
|
(Millions of dollars)
|
|
U.S. Upstream Earnings
|
|
|
$878
|
|
|
|
$2,187
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|
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|
$1,172
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|
$5,977
|
|
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|
|
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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.
27
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.
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Three Months Ended
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Nine Months Ended
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September 30
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September 30
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2009
|
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2008
|
|
2009
|
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2008
|
|
|
(Millions of dollars)
|
|
International Upstream Earnings*
|
|
|
$2,762
|
|
|
|
$3,995
|
|
|
|
$5,256
|
|
|
|
$12,581
|
|
|
|
|
|
|
|
|
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|
|
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* 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.
28
Downstream
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Three Months Ended
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Nine Months Ended
|
|
|
September 30
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September 30
|
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2009
|
|
2008
|
|
2009
|
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2008
|
|
|
(Millions of dollars)
|
|
U.S. Downstream Earnings
|
|
|
$34
|
|
|
|
$1,014
|
|
|
|
$72
|
|
|
|
$336
|
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|
|
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|
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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 companys 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 years 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.
|
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|
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Three Months Ended
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Nine Months Ended
|
|
|
September 30
|
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September 30
|
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2009
|
|
2008
|
|
2009
|
|
2008
|
|
|
(Millions of dollars)
|
|
International Downstream Earnings*
|
|
|
$160
|
|
|
|
$817
|
|
|
|
$1,106
|
|
|
|
$1,013
|
|
|
|
|
|
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|
|
|
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|
|
|
|
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|
* 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 companys 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
29
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
|
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|
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|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
September 30
|
|
September 30
|
|
|
2009
|
|
2008
|
|
2009
|
|
2008
|
|
|
(Millions of dollars)
|
|
Earnings*
|
|
|
$164
|
|
|
|
$70
|
|
|
|
$311
|
|
|
|
$154
|
|
|
|
|
|
|
|
|
|
|
|
|
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|
|
|
|
|
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|
|
|
|
|
|
|
|
|
|
* 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 Chevrons 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
|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
30
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.
31
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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 companys 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
|
|
|
|
$16,681
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effective income tax rates for the 2009 and 2008 third quarters
were 38 percent and 45 percent, respectively. For the
year-to-date
periods, the effective tax rates were 41 and 47 percent,
respectively.
The decline in the effective tax rates between the quarterly and
nine-month periods was generally associated with the same
factors. These factors included the effect in 2009 of relatively
low tax rates on asset sales and deferred-tax benefits, both
related to an international upstream project. In addition, a
greater proportion of before-tax income was earned in 2009 by
equity affiliates than in 2008. (Equity-affiliate income is
reported as a single amount on an after-tax basis on the
Consolidated Statement of Income.)
32
Selected
Operating Data
The following table presents a comparison of selected operating
data:
Selected
Operating Data(1)(2)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 30
|
|
|
September 30
|
|
|
|
2009
|
|
|
2008
|
|
|
2009
|
|
|
2008
|
|
|
U.S. Upstream
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net crude-oil and natural-gas-liquids production (MBPD)
|
|
|
509
|
|
|
|
409
|
|
|
|
472
|
|
|
|
428
|
|
Net natural-gas production (MMCFPD)(3)
|
|
|
1,420
|
|
|
|
1,431
|
|
|
|
1,398
|
|
|
|
1,561
|
|
Net oil-equivalent production (MBOEPD)
|
|
|
745
|
|
|
|
647
|
|
|
|
705
|
|
|
|
688
|
|
Sales of natural gas (MMCFPD)
|
|
|
5,832
|
|
|
|
7,142
|
|
|
|
5,974
|
|
|
|
7,591
|
|
Sales of natural gas liquids (MBPD)
|
|
|
161
|
|
|
|
155
|
|
|
|
158
|
|
|
|
156
|
|
Revenue from net production
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude oil and natural gas liquids ($/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.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
33
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 companys
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 Chevrons 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 companys 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
companys 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 companys 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 Poors Corporation and Aa1 by Moodys Investors
Service. The companys U.S. commercial paper is rated
A-1+ by
Standard and Poors and
P-1 by
Moodys. All of these ratings denote high-quality,
investment-grade securities.
The companys 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 companys 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.
34
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
Chevrons 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 companys 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 companys 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 companys 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.
35
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 Texpets 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
Texpets remediation was properly conducted and that the
remaining environmental damage reflects Petroecuadors
failure to timely fulfill its legal obligations and
Petroecuadors 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
engineers report also asserted that an additional
$8.3 billion could be assessed against Chevron for unjust
enrichment. The engineers report is not binding on the
court. Chevron also believes that the engineers work was
performed and his report prepared in a manner contrary to law
and in violation of the courts 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
engineers 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
36
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 companys 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 companys 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
Texacos 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 companys 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 companys 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
37
have, any significant impact on the companys 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 Chevrons
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
companys major tax jurisdictions, examinations of tax
returns for certain prior tax years had not been completed as of
September 30, 2009. For Chevrons 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 companys 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 companys 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
companys accounting.
38
|
|
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 Chevrons 2008 Annual
Report on
Form 10-K.
|
|
Item 4.
|
Controls
and Procedures
|
(a) Evaluation of disclosure controls and procedures
The companys management has evaluated, with the
participation of the Chief Executive Officer and Chief Financial
Officer, the effectiveness of the companys 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 companys 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 companys internal control over financial
reporting that have materially affected, or were reasonably
likely to materially affect, the companys 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.
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 companys
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 Chevrons 2008
Annual Report on
Form 10-K.
39
|
|
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
companys 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. |
40
|
|
|
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 companys Chief Executive Officer
|
(31.2)
|
|
Rule 13a-14(a)/15d-14(a)
Certification by the companys Chief Financial Officer
|
(32.1)
|
|
Section 1350 Certification by the companys Chief
Executive Officer
|
(32.2)
|
|
Section 1350 Certification by the companys 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.
41
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)
M.A. Humphrey, Vice President and Comptroller
(Principal Accounting Officer and
Duly Authorized Officer)
Date: November 5, 2009
42
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 companys Chief Executive Officer
|
(31.2)*
|
|
Rule 13a-14(a)/15d-14(a)
Certification by the companys Chief Financial Officer
|
(32.1)*
|
|
Section 1350 Certification by the companys Chief
Executive Officer
|
(32.2)*
|
|
Section 1350 Certification by the companys 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.
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.
43