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 June 30,
2011
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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
001-00368
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,
San Ramon, California
(Address of principal
executive offices)
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94583-2324
(Zip
Code)
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Registrants telephone number, including area code:
(925) 842-1000
NONE
(Former name, former address and former fiscal year, 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
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Smaller
reporting
company o
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(Do not check if a smaller reporting company)
Indicate by check mark whether the registrant is a shell company
(as defined in
Rule 12b-2
of the Exchange
Act). Yes o No þ
Indicate the number of shares outstanding of each of the
issuers classes of common stock, as of the latest
practicable date:
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Class
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Outstanding as of June 30, 2011
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Common stock, $.75 par value
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2,002,983,069
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CAUTIONARY
STATEMENTS 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: changing crude oil and natural gas prices; changing
refining, marketing and chemical 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; 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 other pending or future litigation; the
companys future acquisition or disposition of assets and
gains and losses from asset dispositions or impairments;
government-mandated sales, divestitures, recapitalizations,
industry-specific taxes, changes in fiscal terms or restrictions
on scope of company operations; foreign currency movements
compared with the U.S. dollar; the effects of changed
accounting rules under generally accepted accounting principles
promulgated by rule-setting bodies; and the factors set forth
under the heading Risk Factors on pages 32 through
34 of the companys 2010 Annual Report on
Form 10-K.
In addition, such statements could be affected by general
domestic and international economic and political conditions.
Other unpredictable or unknown factors not discussed in this
report could also have material adverse effects on
forward-looking statements.
2
PART I.
FINANCIAL
INFORMATION
Item 1.
Consolidated Financial Statements
CHEVRON
CORPORATION AND SUBSIDIARIES
(Unaudited)
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Three Months Ended
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Six Months Ended
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June 30
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June 30
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2011
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2010
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2011
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2010
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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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$66,671
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$51,051
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$125,083
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$97,792
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Income from equity affiliates
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1,882
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1,650
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3,569
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2,885
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Other income
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395
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303
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|
637
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|
506
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Total Revenues and Other Income
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68,948
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53,004
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129,289
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101,183
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Costs and Other Deductions
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Purchased crude oil and products
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40,759
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30,604
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75,960
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57,748
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Operating expenses
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5,260
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4,591
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10,323
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9,180
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Selling, general and administrative expenses
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1,200
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1,136
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2,300
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2,178
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Exploration expenses
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422
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212
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590
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392
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Depreciation, depletion and amortization
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3,257
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3,141
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6,383
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6,223
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Taxes other than on income*
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4,843
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4,537
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9,404
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9,009
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Interest and debt expense
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17
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37
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Total Costs and Other Deductions
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55,741
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44,238
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104,960
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84,767
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Income Before Income Tax Expense
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13,207
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8,766
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24,329
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16,416
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Income Tax Expense
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5,447
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3,322
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10,330
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6,392
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Net Income
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7,760
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5,444
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13,999
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10,024
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Less: Net income attributable to noncontrolling interests
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28
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35
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56
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63
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Net Income Attributable to Chevron Corporation
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$7,732
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$5,409
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$13,943
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$9,961
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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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$3.88
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$2.71
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$6.99
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$4.99
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Diluted
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$3.85
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$2.70
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$6.94
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$4.97
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Dividends
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$0.78
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$0.72
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$1.50
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$1.40
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Weighted Average Number of Shares Outstanding (000s)
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Basic
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1,994,007
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1,996,393
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1,994,369
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1,995,692
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Diluted
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2,008,995
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2,006,000
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2,008,791
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2,005,114
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* Includes excise, value-added and similar taxes:
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$2,264
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$2,201
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$4,398
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$4,273
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See accompanying notes to consolidated financial statements.
3
CHEVRON
CORPORATION AND SUBSIDIARIES
(Unaudited)
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Three Months
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Six Months
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Ended
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Ended
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June 30
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June 30
|
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2011
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2010
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2011
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2010
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(Millions of dollars)
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Net Income
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$
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7,760
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$
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5,444
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$
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13,999
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$
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10,024
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Currency translation adjustment
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18
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(16
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)
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51
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(13
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)
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Unrealized holding loss on securities:
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Net loss arising during period
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(10
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)
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(3
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)
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(11
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)
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(4
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)
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Derivatives:
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Net derivatives gain on hedge transactions
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11
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23
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24
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Reclassification to net income of net realized (gain) loss
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(2
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)
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3
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(3
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)
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3
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Income taxes on derivatives transactions
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(3
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)
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(10
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)
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1
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(10
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)
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Total
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6
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16
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(2
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)
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17
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Defined benefit plans:
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Actuarial loss:
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Amortization to net income of net actuarial loss
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176
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167
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386
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332
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Actuarial gain arising during period
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4
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55
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Prior service cost:
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Amortization to net income of net prior service (credits) costs
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(5
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)
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(15
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)
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8
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(30
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)
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Defined benefit plans sponsored by equity affiliates
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10
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7
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22
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14
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Income taxes on defined benefit plans
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(63
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)
|
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|
(63
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)
|
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(160
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)
|
|
|
(121
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)
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Total
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|
122
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|
|
96
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|
311
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|
|
|
195
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|
|
|
|
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Other Comprehensive Gain, Net of Tax
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|
136
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|
93
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|
349
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|
|
195
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|
|
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Comprehensive Income
|
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|
7,896
|
|
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|
5,537
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|
14,348
|
|
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|
10,219
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|
Comprehensive income attributable to noncontrolling interests
|
|
|
(28
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)
|
|
|
(35
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)
|
|
|
(56
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)
|
|
|
(63
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)
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|
|
|
|
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|
|
|
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Comprehensive Income Attributable to Chevron Corporation
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|
$
|
7,868
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|
|
$
|
5,502
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|
|
$
|
14,292
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|
|
$
|
10,156
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to consolidated financial statements.
4
CHEVRON
CORPORATION AND SUBSIDIARIES
(Unaudited)
|
|
|
|
|
|
|
|
|
|
|
At June 30
|
|
At December 31
|
|
|
2011
|
|
2010
|
|
|
(Millions of dollars, except
|
|
|
per-share amounts)
|
|
ASSETS
|
Cash and cash equivalents
|
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|
$13,335
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$14,060
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Time deposits
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4,408
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|
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|
2,855
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|
Marketable securities
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|
221
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|
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|
155
|
|
Accounts and notes receivable, net
|
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|
23,613
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|
|
|
20,759
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|
Inventories:
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Crude oil and petroleum products
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5,232
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3,589
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|
Chemicals
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|
434
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|
395
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|
Materials, supplies and other
|
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|
1,620
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|
|
|
1,509
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|
|
|
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|
|
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|
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Total inventories
|
|
|
7,286
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|
|
|
5,493
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|
Prepaid expenses and other current assets
|
|
|
5,143
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|
|
|
5,519
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|
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|
|
|
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|
Total Current Assets
|
|
|
54,006
|
|
|
|
48,841
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Long-term receivables, net
|
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|
2,114
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|
|
|
2,077
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Investments and advances
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|
21,724
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|
|
|
21,520
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Properties, plant and equipment, at cost
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220,107
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|
|
|
207,367
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|
Less: Accumulated depreciation, depletion and amortization
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105,353
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|
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|
102,863
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Properties, plant and equipment, net
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|
114,754
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|
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|
104,504
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|
Deferred charges and other assets
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|
3,109
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|
|
|
3,210
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|
Goodwill
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|
4,654
|
|
|
|
4,617
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|
Assets held for sale
|
|
|
1,356
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Assets
|
|
|
$201,717
|
|
|
|
$184,769
|
|
|
|
|
|
|
|
|
|
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|
LIABILITIES AND EQUITY
|
Short-term debt
|
|
|
$1,902
|
|
|
|
$187
|
|
Accounts payable
|
|
|
22,764
|
|
|
|
19,259
|
|
Accrued liabilities
|
|
|
4,906
|
|
|
|
5,324
|
|
Federal and other taxes on income
|
|
|
4,098
|
|
|
|
2,776
|
|
Other taxes payable
|
|
|
1,550
|
|
|
|
1,466
|
|
|
|
|
|
|
|
|
|
|
Total Current Liabilities
|
|
|
35,220
|
|
|
|
29,012
|
|
Long-term debt
|
|
|
9,484
|
|
|
|
11,003
|
|
Capital lease obligations
|
|
|
134
|
|
|
|
286
|
|
Deferred credits and other noncurrent obligations
|
|
|
18,829
|
|
|
|
19,264
|
|
Noncurrent deferred income taxes
|
|
|
15,286
|
|
|
|
12,697
|
|
Reserves for employee benefit plans
|
|
|
6,334
|
|
|
|
6,696
|
|
|
|
|
|
|
|
|
|
|
Total Liabilities
|
|
|
85,287
|
|
|
|
78,958
|
|
|
|
|
|
|
|
|
|
|
Preferred stock (authorized 100,000,000 shares,
$1.00 par value, none issued)
|
|
|
|
|
|
|
|
|
Common stock (authorized 6,000,000,000 shares,
$.75 par value, 2,442,676,580 shares issued at
June 30, 2011, and December 31, 2010)
|
|
|
1,832
|
|
|
|
1,832
|
|
Capital in excess of par value
|
|
|
15,027
|
|
|
|
14,796
|
|
Retained earnings
|
|
|
130,592
|
|
|
|
119,641
|
|
Accumulated other comprehensive loss
|
|
|
(4,117
|
)
|
|
|
(4,466
|
)
|
Deferred compensation and benefit plan trust
|
|
|
(299
|
)
|
|
|
(311
|
)
|
Treasury stock, at cost (439,693,511 and 435,195,799 shares
at June 30, 2011, and December 31, 2010, respectively)
|
|
|
(27,382
|
)
|
|
|
(26,411
|
)
|
|
|
|
|
|
|
|
|
|
Total Chevron Corporation Stockholders Equity
|
|
|
115,653
|
|
|
|
105,081
|
|
Noncontrolling interests
|
|
|
777
|
|
|
|
730
|
|
|
|
|
|
|
|
|
|
|
Total Equity
|
|
|
116,430
|
|
|
|
105,811
|
|
|
|
|
|
|
|
|
|
|
Total Liabilities and Equity
|
|
|
$201,717
|
|
|
|
$184,769
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to consolidated financial statements.
5
CHEVRON
CORPORATION AND SUBSIDIARIES
(Unaudited)
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended
|
|
|
|
June 30
|
|
|
|
2011
|
|
|
2010
|
|
|
|
(Millions of dollars)
|
|
|
Operating Activities
|
|
|
|
|
|
|
|
|
Net Income
|
|
$
|
13,999
|
|
|
$
|
10,024
|
|
Adjustments
|
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization
|
|
|
6,383
|
|
|
|
6,223
|
|
Dry hole expense
|
|
|
204
|
|
|
|
128
|
|
Distributions more (less) than income from equity affiliates
|
|
|
449
|
|
|
|
(325
|
)
|
Net before-tax gains on asset retirements and sales
|
|
|
(420
|
)
|
|
|
(301
|
)
|
Net foreign currency effects
|
|
|
27
|
|
|
|
(1
|
)
|
Deferred income tax provision
|
|
|
348
|
|
|
|
(237
|
)
|
Net increase in operating working capital
|
|
|
(179
|
)
|
|
|
(367
|
)
|
Increase in long-term receivables
|
|
|
(32
|
)
|
|
|
(67
|
)
|
Decrease in other deferred charges
|
|
|
69
|
|
|
|
8
|
|
Cash contributions to employee pension plans
|
|
|
(557
|
)
|
|
|
(347
|
)
|
Other
|
|
|
213
|
|
|
|
382
|
|
|
|
|
|
|
|
|
|
|
Net Cash Provided by Operating Activities
|
|
|
20,504
|
|
|
|
15,120
|
|
|
|
|
|
|
|
|
|
|
Investing Activities
|
|
|
|
|
|
|
|
|
Acquisition of Atlas Energy
|
|
|
(3,014
|
)
|
|
|
|
|
Advance to Atlas Energy
|
|
|
(403
|
)
|
|
|
|
|
Capital expenditures
|
|
|
(12,418
|
)
|
|
|
(8,519
|
)
|
Proceeds and deposits related to asset sales
|
|
|
626
|
|
|
|
393
|
|
Net purchases of time deposits
|
|
|
(1,553
|
)
|
|
|
(3,753
|
)
|
Net (purchases) sales of marketable securities
|
|
|
(53
|
)
|
|
|
39
|
|
Repayment of loans by equity affiliates
|
|
|
182
|
|
|
|
169
|
|
Net sales of other short-term investments
|
|
|
212
|
|
|
|
87
|
|
|
|
|
|
|
|
|
|
|
Net Cash Used for Investing Activities
|
|
|
(16,421
|
)
|
|
|
(11,584
|
)
|
|
|
|
|
|
|
|
|
|
Financing Activities
|
|
|
|
|
|
|
|
|
Net borrowings of short-term obligations
|
|
|
253
|
|
|
|
36
|
|
Repayments of long-term debt and other financing obligations
|
|
|
(1,231
|
)
|
|
|
(77
|
)
|
Cash dividends common stock
|
|
|
(2,992
|
)
|
|
|
(2,794
|
)
|
Distributions to noncontrolling interests
|
|
|
(28
|
)
|
|
|
(31
|
)
|
Net (purchases) sales of treasury shares
|
|
|
(886
|
)
|
|
|
142
|
|
|
|
|
|
|
|
|
|
|
Net Cash Used for Financing Activities
|
|
|
(4,884
|
)
|
|
|
(2,724
|
)
|
|
|
|
|
|
|
|
|
|
Effect of Exchange Rate Changes on Cash and Cash
Equivalents
|
|
|
76
|
|
|
|
(132
|
)
|
|
|
|
|
|
|
|
|
|
Net Change in Cash and Cash Equivalents
|
|
|
(725
|
)
|
|
|
680
|
|
Cash and Cash Equivalents at January 1
|
|
|
14,060
|
|
|
|
8,716
|
|
|
|
|
|
|
|
|
|
|
Cash and Cash Equivalents at June 30
|
|
$
|
13,335
|
|
|
$
|
9,396
|
|
|
|
|
|
|
|
|
|
|
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
six-month periods ended June 30, 2011, 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 2010 Annual Report on
Form 10-K.
|
|
Note 2.
|
Noncontrolling
Interests
|
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 six months of 2011 and 2010 is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2011
|
|
2010
|
|
|
Chevron Corporation
|
|
Noncontrolling
|
|
Total
|
|
Chevron Corporation
|
|
Noncontrolling
|
|
Total
|
|
|
Stockholders Equity
|
|
Interest
|
|
Equity
|
|
Stockholders Equity
|
|
Interest
|
|
Equity
|
|
|
(Millions of dollars)
|
|
Balance at January 1
|
|
|
$105,081
|
|
|
|
$730
|
|
|
|
$105,811
|
|
|
|
$91,914
|
|
|
|
$647
|
|
|
|
$92,561
|
|
Net income
|
|
|
13,943
|
|
|
|
56
|
|
|
|
13,999
|
|
|
|
9,961
|
|
|
|
63
|
|
|
|
10,024
|
|
Dividends
|
|
|
(2,992
|
)
|
|
|
|
|
|
|
(2,992
|
)
|
|
|
(2,794
|
)
|
|
|
|
|
|
|
(2,794
|
)
|
Distributions to noncontrolling interests
|
|
|
|
|
|
|
(28
|
)
|
|
|
(28
|
)
|
|
|
|
|
|
|
(31
|
)
|
|
|
(31
|
)
|
Treasury shares, net
|
|
|
(971
|
)
|
|
|
|
|
|
|
(971
|
)
|
|
|
170
|
|
|
|
|
|
|
|
170
|
|
Other changes, net*
|
|
|
592
|
|
|
|
19
|
|
|
|
611
|
|
|
|
318
|
|
|
|
43
|
|
|
|
361
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at June 30
|
|
|
$115,653
|
|
|
|
$777
|
|
|
|
$116,430
|
|
|
|
$99,569
|
|
|
|
$722
|
|
|
|
$100,291
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* |
|
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:
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended
|
|
|
|
June 30
|
|
|
|
2011
|
|
|
2010
|
|
|
|
(Millions of dollars)
|
|
|
Increase in accounts and notes receivable
|
|
$
|
(2,756
|
)
|
|
$
|
(124
|
)
|
Increase in inventories
|
|
|
(1,823
|
)
|
|
|
(382
|
)
|
Decrease (increase) in prepaid expenses and other current assets
|
|
|
84
|
|
|
|
(329
|
)
|
Increase (decrease) in accounts payable and accrued liabilities
|
|
|
2,980
|
|
|
|
(272
|
)
|
Increase in income and other taxes payable
|
|
|
1,336
|
|
|
|
740
|
|
|
|
|
|
|
|
|
|
|
Net increase in operating working capital
|
|
$
|
(179
|
)
|
|
$
|
(367
|
)
|
|
|
|
|
|
|
|
|
|
The Net increase in operating working capital
includes reductions of $116 million and $23 million
for excess income tax benefits associated with stock options
exercised during the six months ended June 30, 2011, and
2010, respectively. These amounts are offset by an equal amount
in Net (purchases) sales of treasury shares.
Net Cash Provided by Operating Activities included
the following cash payments for interest on debt and for income
taxes:
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended
|
|
|
June 30
|
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Interest on debt (net of capitalized interest)
|
|
$
|
|
|
|
$
|
34
|
|
Income taxes
|
|
|
8,554
|
|
|
|
5,936
|
|
The Acquisition of Atlas Energy reflects the
$3.0 billion of cash paid for all the common shares of
Atlas. An Advance to Atlas Energy of
$403 million was made to facilitate the purchase of a
49 percent interest in Laurel Mountain Midstream LLC on the
day of closing. The Net increase in operating working
capital includes $184 million for payments made in
connection with Atlas equity awards subsequent to the
acquisition.
The Net purchases of time deposits consisted of the
following gross amounts:
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30
|
|
|
|
2011
|
|
|
2010
|
|
|
|
(Millions of dollars)
|
|
|
Time deposits purchased
|
|
$
|
(3,980
|
)
|
|
$
|
(4,348
|
)
|
Time deposits matured
|
|
|
2,427
|
|
|
|
595
|
|
|
|
|
|
|
|
|
|
|
Net purchases of time deposits
|
|
$
|
(1,553
|
)
|
|
$
|
(3,753
|
)
|
|
|
|
|
|
|
|
|
|
The Net (purchases) sales of marketable securities
consisted of the following gross amounts:
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended
|
|
|
June 30
|
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Marketable securities purchased
|
|
|
$(86
|
)
|
|
|
$
|
|
Marketable securities sold
|
|
|
33
|
|
|
|
39
|
|
|
|
|
|
|
|
|
|
|
Net (purchases) sales of marketable securities
|
|
|
$(53
|
)
|
|
|
$39
|
|
|
|
|
|
|
|
|
|
|
The Repayments of long-term debt and other financing
obligations includes $761 million for repayment of
Atlas debt and $271 million for payoff of the Atlas
revolving credit facility. Refer to Note 16, on
page 22, for additional discussion of the Atlas acquisition.
The Net (purchase) sales of treasury shares
represents the cost of common shares acquired less the cost of
shares issued for share-based compensation plans. Purchases
totaled $1.8 billion and $13 million in the first six
months of 2011 and 2010, respectively. During the first six
months of 2011, the company purchased 17.3 million common
8
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
shares for $1.75 billion under its ongoing share repurchase
program. No purchases were made under the companys stock
repurchase program in the 2010 period.
The major components of Capital expenditures and the
reconciliation of this amount to the capital and exploratory
expenditures, including equity affiliates, are as follows:
|
|
|
|
|
|
|
|
|
|
|
Six Months
|
|
|
|
Ended
|
|
|
|
June 30
|
|
|
|
2011
|
|
|
2010
|
|
|
|
(Millions of dollars)
|
|
|
Additions to properties, plant and equipment
|
|
$
|
11,877
|
|
|
$
|
8,080
|
|
Additions to investments
|
|
|
410
|
|
|
|
391
|
|
Current year dry hole expenditures
|
|
|
195
|
|
|
|
116
|
|
Payments for other liabilities and assets, net
|
|
|
(64
|
)
|
|
|
(68
|
)
|
|
|
|
|
|
|
|
|
|
Capital expenditures
|
|
|
12,418
|
|
|
|
8,519
|
|
Expensed exploration expenditures
|
|
|
386
|
|
|
|
264
|
|
Assets acquired through capital lease obligations
|
|
|
1
|
|
|
|
33
|
|
|
|
|
|
|
|
|
|
|
Capital and exploratory expenditures, excluding equity affiliates
|
|
|
12,805
|
|
|
|
8,816
|
|
Companys share of expenditures by equity affiliates
|
|
|
584
|
|
|
|
609
|
|
|
|
|
|
|
|
|
|
|
Capital and exploratory expenditures, including equity affiliates
|
|
$
|
13,389
|
|
|
$
|
9,425
|
|
|
|
|
|
|
|
|
|
|
|
|
Note 4.
|
Operating
Segments and Geographic Data
|
Although each subsidiary of Chevron is responsible for its own
affairs, Chevron Corporation manages its investments in these
subsidiaries and their affiliates. The investments are grouped
into two business segments, Upstream and Downstream,
representing the companys reportable segments
and operating segments as defined in accounting
standards for segment reporting (ASC 280). Upstream operations
consist primarily of exploring for, developing and producing
crude oil and natural gas; liquefaction, transportation and
regasification associated with liquefied natural gas (LNG);
transporting crude oil by major international oil export
pipelines; processing, transporting, storage and marketing of
natural gas; and a
gas-to-liquids
project. Downstream operations consist primarily of refining of
crude oil into petroleum products; marketing of crude oil and
refined products; transporting of crude oil and refined products
by pipeline, marine vessel, motor equipment and rail car; and
manufacturing and marketing of commodity petrochemicals,
plastics for industrial uses, and fuel and lubricant additives.
All Other activities of the company include mining operations,
power generation businesses, worldwide cash management and debt
financing activities, corporate administrative functions,
insurance operations, real estate activities, energy services,
and alternative fuels and technology.
The segments are separately managed for investment purposes
under a structure that includes segment managers who
report to the companys chief operating decision
maker (CODM) (terms as defined in ASC 280). The CODM
is the companys Executive Committee (EXCOM), a committee
of senior officers that includes the Chief Executive Officer,
and EXCOM reports to the Board of Directors of Chevron
Corporation.
The operating segments represent components of the company, as
described in accounting standards for segment reporting (ASC
280), that engage in activities (a) from which revenues are
earned and expenses are incurred; (b) whose operating
results are regularly reviewed by the CODM, which makes
decisions about resources to be allocated to the segments and
assesses their performance; and (c) for which discrete
financial information is available.
Segment managers for the reportable segments are directly
accountable to and maintain regular contact with the
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 EXCOM also have individual management
responsibilities and participate in other committees for
purposes other than acting as the CODM.
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).
9
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
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 six-month periods ended June 30, 2011 and 2010
are presented in the following table:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Six Months Ended
|
|
|
|
June 30
|
|
|
June 30
|
|
Segment Earnings
|
|
2011
|
|
|
2010
|
|
|
2011
|
|
|
2010
|
|
|
|
(Millions of dollars)
|
|
|
Upstream
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
$
|
1,950
|
|
|
$
|
1,090
|
|
|
$
|
3,399
|
|
|
$
|
2,246
|
|
International
|
|
|
4,921
|
|
|
|
3,452
|
|
|
|
9,449
|
|
|
|
7,020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Upstream
|
|
|
6,871
|
|
|
|
4,542
|
|
|
|
12,848
|
|
|
|
9,266
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Downstream
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
|
564
|
|
|
|
433
|
|
|
|
1,006
|
|
|
|
515
|
|
International
|
|
|
480
|
|
|
|
542
|
|
|
|
660
|
|
|
|
656
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Downstream
|
|
|
1,044
|
|
|
|
975
|
|
|
|
1,666
|
|
|
|
1,171
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Segment Earnings
|
|
|
7,915
|
|
|
|
5,517
|
|
|
|
14,514
|
|
|
|
10,437
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
All Other
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest Expense
|
|
|
|
|
|
|
(14
|
)
|
|
|
|
|
|
|
(30
|
)
|
Interest Income
|
|
|
19
|
|
|
|
23
|
|
|
|
37
|
|
|
|
33
|
|
Other
|
|
|
(202
|
)
|
|
|
(117
|
)
|
|
|
(608
|
)
|
|
|
(479
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income Attributable to Chevron Corporation
|
|
$
|
7,732
|
|
|
$
|
5,409
|
|
|
$
|
13,943
|
|
|
$
|
9,961
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Segment Assets Segment assets do not include intercompany
investments or intercompany receivables. All Other
assets consist primarily of worldwide cash, cash equivalents,
time deposits and marketable securities; real estate;
information systems; mining operations; power generation
businesses; alternative fuels; technology companies; and assets
of the corporate administrative functions. Segment assets at
June 30, 2011, and December 31, 2010, are as follows:
|
|
|
|
|
|
|
|
|
|
|
At June 30
|
|
At December 31
|
Segment Assets
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Upstream
|
|
|
|
|
|
|
|
|
United States
|
|
|
$ 35,105
|
|
|
|
$ 26,319
|
|
International
|
|
|
92,732
|
|
|
|
89,306
|
|
Goodwill
|
|
|
4,654
|
|
|
|
4,617
|
|
|
|
|
|
|
|
|
|
|
Total Upstream
|
|
|
132,491
|
|
|
|
120,242
|
|
|
|
|
|
|
|
|
|
|
Downstream
|
|
|
|
|
|
|
|
|
United States
|
|
|
22,228
|
|
|
|
21,406
|
|
International
|
|
|
23,866
|
|
|
|
20,559
|
|
|
|
|
|
|
|
|
|
|
Total Downstream
|
|
|
46,094
|
|
|
|
41,965
|
|
|
|
|
|
|
|
|
|
|
Total Segment Assets
|
|
|
178,585
|
|
|
|
162,207
|
|
|
|
|
|
|
|
|
|
|
All Other
|
|
|
|
|
|
|
|
|
United States
|
|
|
8,790
|
|
|
|
11,125
|
|
International
|
|
|
14,342
|
|
|
|
11,437
|
|
|
|
|
|
|
|
|
|
|
Total All Other
|
|
|
23,132
|
|
|
|
22,562
|
|
|
|
|
|
|
|
|
|
|
Total Assets United States
|
|
|
66,123
|
|
|
|
58,850
|
|
Total Assets International
|
|
|
130,940
|
|
|
|
121,302
|
|
Goodwill
|
|
|
4,654
|
|
|
|
4,617
|
|
|
|
|
|
|
|
|
|
|
Total Assets
|
|
|
$201,717
|
|
|
|
$184,769
|
|
|
|
|
|
|
|
|
|
|
10
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Segment Sales and Other Operating Revenues Segment sales
and other operating revenues, including internal transfers, for
the three- and six-month periods ended June 30, 2011 and
2010, are presented in the following table. Products are
transferred between operating segments at internal product
values that approximate market prices. Revenues for the upstream
segment are derived primarily from the production and sale of
crude oil and natural gas, as well as the sale of third-party
production of natural gas. Revenues for the downstream segment
are derived from the refining and marketing of petroleum
products such as gasoline, jet fuel, gas oils, lubricants,
residual fuel oils and other products derived from crude oil.
This segment also generates revenues from the manufacture and
sale of fuel and lubricant additives and the transportation and
trading of refined products and crude oil. All Other
activities include revenues from mining operations, power
generation businesses, insurance operations, real estate
activities and technology companies.
Sales and
Other Operating Revenues
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Six Months Ended
|
|
|
|
June 30
|
|
|
June 30
|
|
|
|
2011
|
|
|
2010
|
|
|
2011
|
|
|
2010
|
|
|
|
(Millions of dollars)
|
|
|
Upstream
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
$
|
7,357
|
|
|
$
|
5,722
|
|
|
$
|
14,023
|
|
|
$
|
12,315
|
|
International
|
|
|
14,538
|
|
|
|
10,110
|
|
|
|
27,407
|
|
|
|
19,658
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Subtotal
|
|
|
21,895
|
|
|
|
15,832
|
|
|
|
41,430
|
|
|
|
31,973
|
|
Intersegment Elimination United States
|
|
|
(4,897
|
)
|
|
|
(3,370
|
)
|
|
|
(9,162
|
)
|
|
|
(6,843
|
)
|
Intersegment Elimination International
|
|
|
(9,197
|
)
|
|
|
(5,813
|
)
|
|
|
(17,650
|
)
|
|
|
(11,518
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Upstream
|
|
|
7,801
|
|
|
|
6,649
|
|
|
|
14,618
|
|
|
|
13,612
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Downstream
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
|
24,612
|
|
|
|
19,222
|
|
|
|
46,046
|
|
|
|
36,940
|
|
International
|
|
|
34,180
|
|
|
|
25,093
|
|
|
|
64,237
|
|
|
|
47,060
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Subtotal
|
|
|
58,792
|
|
|
|
44,315
|
|
|
|
110,283
|
|
|
|
84,000
|
|
Intersegment Elimination United States
|
|
|
(23
|
)
|
|
|
(21
|
)
|
|
|
(43
|
)
|
|
|
(49
|
)
|
Intersegment Elimination International
|
|
|
(31
|
)
|
|
|
(26
|
)
|
|
|
(51
|
)
|
|
|
(48
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Downstream
|
|
|
58,738
|
|
|
|
44,268
|
|
|
|
110,189
|
|
|
|
83,903
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
All Other
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
|
397
|
|
|
|
381
|
|
|
|
762
|
|
|
|
675
|
|
International
|
|
|
12
|
|
|
|
18
|
|
|
|
22
|
|
|
|
33
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Subtotal
|
|
|
409
|
|
|
|
399
|
|
|
|
784
|
|
|
|
708
|
|
Intersegment Elimination United States
|
|
|
(266
|
)
|
|
|
(254
|
)
|
|
|
(488
|
)
|
|
|
(413
|
)
|
Intersegment Elimination International
|
|
|
(11
|
)
|
|
|
(11
|
)
|
|
|
(20
|
)
|
|
|
(18
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total All Other
|
|
|
132
|
|
|
|
134
|
|
|
|
276
|
|
|
|
277
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Sales and Other Operating Revenues
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
|
32,366
|
|
|
|
25,325
|
|
|
|
60,831
|
|
|
|
49,930
|
|
International
|
|
|
48,730
|
|
|
|
35,221
|
|
|
|
91,666
|
|
|
|
66,751
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Subtotal
|
|
|
81,096
|
|
|
|
60,546
|
|
|
|
152,497
|
|
|
|
116,681
|
|
Intersegment Elimination United States
|
|
|
(5,186
|
)
|
|
|
(3,645
|
)
|
|
|
(9,693
|
)
|
|
|
(7,305
|
)
|
Intersegment Elimination International
|
|
|
(9,239
|
)
|
|
|
(5,850
|
)
|
|
|
(17,721
|
)
|
|
|
(11,584
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Sales and Other Operating Revenues
|
|
$
|
66,671
|
|
|
$
|
51,051
|
|
|
$
|
125,083
|
|
|
$
|
97,792
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
11
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. The summarized financial
information for CUSA and its consolidated subsidiaries is as
follows:
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended
|
|
|
|
June 30
|
|
|
|
2011
|
|
|
2010
|
|
|
|
(Millions of dollars)
|
|
|
Sales and other operating revenues
|
|
$
|
94,913
|
|
|
$
|
71,612
|
|
Costs and other deductions
|
|
|
89,966
|
|
|
|
68,934
|
|
Net income attributable to CUSA
|
|
|
3,690
|
|
|
|
2,019
|
|
|
|
|
|
|
|
|
|
|
|
|
At June 30
|
|
At December 31
|
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Current assets
|
|
|
$34,569
|
|
|
|
$29,211
|
|
Other assets
|
|
|
44,212
|
|
|
|
35,294
|
|
Current liabilities
|
|
|
20,890
|
|
|
|
18,098
|
|
Other liabilities
|
|
|
24,314
|
|
|
|
16,785
|
|
|
|
|
|
|
|
|
|
|
Total CUSA net equity
|
|
|
$33,577
|
|
|
|
$29,622
|
|
|
|
|
|
|
|
|
|
|
Memo: Total debt
|
|
|
$14,382
|
|
|
|
$ 8,284
|
|
|
|
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
|
|
|
Six Months Ended
|
|
|
|
June 30
|
|
|
June 30
|
|
|
|
2011
|
|
|
2010
|
|
|
2011
|
|
|
2010
|
|
|
|
(Millions of dollars)
|
|
|
Sales and other operating revenues
|
|
$
|
196
|
|
|
$
|
250
|
|
|
$
|
422
|
|
|
$
|
494
|
|
Costs and other deductions
|
|
|
227
|
|
|
|
264
|
|
|
|
489
|
|
|
|
527
|
|
Net loss attributable to CTC
|
|
|
(32
|
)
|
|
|
(5
|
)
|
|
|
(67
|
)
|
|
|
(26
|
)
|
|
|
|
|
|
|
|
|
|
|
|
At June 30
|
|
At December 31
|
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Current assets
|
|
|
$ 64
|
|
|
|
$209
|
|
Other assets
|
|
|
252
|
|
|
|
201
|
|
Current liabilities
|
|
|
78
|
|
|
|
101
|
|
Other liabilities
|
|
|
70
|
|
|
|
75
|
|
|
|
|
|
|
|
|
|
|
Total CTC net equity
|
|
|
$168
|
|
|
|
$234
|
|
|
|
|
|
|
|
|
|
|
There were no restrictions on CTCs ability to pay
dividends or make loans or advances at June 30, 2011.
12
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Taxes on income for the second quarter and first six months of
2011 were $5.4 billion and $10.3 billion,
respectively, compared with $3.3 billion and
$6.4 billion for the corresponding periods in 2010. The
associated effective tax rates (calculated as the amount of
Income Tax Expense divided by Income Before Income Tax Expense)
for the second quarters of 2011 and 2010 were 41 percent
and 38 percent, respectively. For the comparative six-month
periods, the effective tax rates were 42 percent and
39 percent, respectively.
The increase in the overall effective tax rates in both the
quarterly and six-month comparisons primarily reflected higher
effective tax rates in international upstream operations. For
both comparative periods, the higher international upstream
effective tax rates were driven primarily by a reduced effect of
non-U.S. tax
benefits and increased withholding taxes in the current year
periods. Additionally, for the quarterly comparison, foreign
currency remeasurement impacts caused an increase in the
effective tax rate.
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 June 30, 2011. For these
jurisdictions, the latest years for which income tax
examinations had been finalized were as follows: United
States 2007, Nigeria 2000,
Angola 2001 and Saudi Arabia 2003.
The company engages in ongoing discussions with tax authorities
regarding the resolution of tax matters in the various
jurisdictions. Both the outcome of these tax matters and the
timing of resolution
and/or
closure of the tax audits are highly uncertain. However, it is
reasonably possible that developments on tax matters in certain
tax jurisdictions may result in significant increases or
decreases in the companys total unrecognized tax benefits
within the next 12 months. Given the number of years that
still remain subject to examination and the number of matters
being examined in the various tax jurisdictions, the company is
unable to estimate the range of possible adjustments to the
balance of unrecognized tax benefits.
|
|
Note 8.
|
Employee
Benefits
|
Chevron has defined benefit pension plans for many employees.
The company typically prefunds defined benefit plans as required
by local regulations or in certain situations where prefunding
provides economic advantages. In the United States, all
qualified plans are subject to the Employee Retirement Income
Security Act (ERISA) minimum funding standard. The company does
not typically fund U.S. nonqualified pension plans
that are not subject to funding requirements under laws and
regulations because contributions to these pension plans may be
less economic and investment returns may be less attractive than
the companys other investment alternatives.
The company also sponsors other postretirement (OPEB) plans that
provide medical and dental benefits, as well as life insurance
for some active and qualifying retired employees. The plans are
unfunded, and the company and the retirees share the costs.
Medical coverage for Medicare-eligible retirees in the
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.
13
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
The components of net periodic benefit costs for 2011 and 2010
are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Six Months Ended
|
|
|
|
June 30
|
|
|
June 30
|
|
|
|
2011
|
|
|
2010
|
|
|
2011
|
|
|
2010
|
|
|
|
(Millions of dollars)
|
|
|
Pension Benefits
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service cost
|
|
$
|
93
|
|
|
$
|
84
|
|
|
$
|
187
|
|
|
$
|
168
|
|
Interest cost
|
|
|
115
|
|
|
|
121
|
|
|
|
231
|
|
|
|
243
|
|
Expected return on plan assets
|
|
|
(153
|
)
|
|
|
(134
|
)
|
|
|
(306
|
)
|
|
|
(269
|
)
|
Amortization of prior service credits
|
|
|
(2
|
)
|
|
|
(2
|
)
|
|
|
(4
|
)
|
|
|
(4
|
)
|
Amortization of actuarial losses
|
|
|
78
|
|
|
|
79
|
|
|
|
155
|
|
|
|
159
|
|
Settlement losses
|
|
|
53
|
|
|
|
55
|
|
|
|
144
|
|
|
|
110
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total United States
|
|
|
184
|
|
|
|
203
|
|
|
|
407
|
|
|
|
407
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
International
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service cost
|
|
|
43
|
|
|
|
40
|
|
|
|
88
|
|
|
|
76
|
|
Interest cost
|
|
|
80
|
|
|
|
79
|
|
|
|
162
|
|
|
|
152
|
|
Expected return on plan assets
|
|
|
(66
|
)
|
|
|
(62
|
)
|
|
|
(137
|
)
|
|
|
(120
|
)
|
Amortization of prior service costs
|
|
|
6
|
|
|
|
6
|
|
|
|
12
|
|
|
|
11
|
|
Amortization of actuarial losses
|
|
|
30
|
|
|
|
26
|
|
|
|
56
|
|
|
|
50
|
|
Curtailment losses
|
|
|
9
|
|
|
|
|
|
|
|
36
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total International
|
|
|
102
|
|
|
|
89
|
|
|
|
217
|
|
|
|
169
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Periodic Pension Benefit Costs
|
|
$
|
286
|
|
|
$
|
292
|
|
|
$
|
624
|
|
|
$
|
576
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other Benefits*
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service cost
|
|
$
|
16
|
|
|
$
|
9
|
|
|
$
|
30
|
|
|
$
|
19
|
|
Interest cost
|
|
|
45
|
|
|
|
43
|
|
|
|
90
|
|
|
|
86
|
|
Amortization of prior service credits
|
|
|
(18
|
)
|
|
|
(19
|
)
|
|
|
(36
|
)
|
|
|
(37
|
)
|
Amortization of actuarial losses
|
|
|
15
|
|
|
|
7
|
|
|
|
31
|
|
|
|
13
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Periodic Other Benefit Costs
|
|
$
|
58
|
|
|
$
|
40
|
|
|
$
|
115
|
|
|
$
|
81
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* |
|
Includes costs for U.S. and international OPEB plans.
Obligations for plans outside the U.S. are not significant
relative to the companys total OPEB obligation. |
At the end of 2010, the company estimated it would contribute
$950 million to employee pension plans during 2011
(composed of $650 million for the U.S. plans and
$300 million for the international plans). Through
June 30, 2011, a total of $557 million was contributed
(including $374 million to the U.S. plans). In July
2011, the company contributed $750 million to the
U.S. plans. Total contributions for the full year are
currently estimated to be $1.45 billion ($1.15 billion
for the U.S. plans and $300 million for the
international plans). Actual contribution amounts are dependent
upon plan investment returns, changes in pension obligations,
regulatory requirements and other economic factors. Additional
funding may ultimately be required if investment returns are
insufficient to offset increases in plan obligations.
During the first six months of 2011, the company contributed
$99 million to its OPEB plans. The company anticipates
contributing about $126 million during the remainder of
2011.
MTBE Chevron and many other companies in the petroleum
industry have used methyl tertiary butyl ether (MTBE) as a
gasoline additive. Chevron is a party to 20 pending lawsuits and
claims, the majority of which involve numerous other petroleum
marketers and refiners. Resolution of these lawsuits and claims
may ultimately require the company to correct or ameliorate the
alleged effects on the environment of prior release of MTBE by
the company or other parties. Additional lawsuits and claims
related to the use of MTBE, including personal-injury claims,
may
14
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
be filed in the future. The companys ultimate exposure
related to pending lawsuits and claims is not determinable, but
could be material to net income in any one period. The company
no longer uses MTBE in the manufacture of gasoline in the United
States.
Ecuador Chevron is a defendant in a civil lawsuit before
the Superior Court of Nueva Loja in Lago Agrio, Ecuador, brought
in May 2003 by plaintiffs who claim to be representatives of
certain residents of an area where an oil production consortium
formerly had operations. The lawsuit alleges damage to the
environment from the oil exploration and production operations
and seeks unspecified damages to fund environmental remediation
and restoration of the alleged environmental harm, plus a health
monitoring program. Until 1992, Texaco Petroleum Company
(Texpet), a subsidiary of Texaco Inc., was a minority member of
this consortium with Petroecuador, the Ecuadorian state-owned
oil company, as the majority partner; since 1990, the operations
have been conducted solely by Petroecuador. At the conclusion of
the consortium and following an independent third-party
environmental audit of the concession area, Texpet entered into
a formal agreement with the Republic of Ecuador and Petroecuador
for Texpet to remediate specific sites assigned by the
government in proportion to 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; third,
that the claims are barred by the statute of limitations in
Ecuador; and, fourth, that the lawsuit is also barred by the
releases from liability previously given to Texpet by the
Republic of Ecuador and Petroecuador and by the pertinent
provincial and municipal governments. With regard to the facts,
the company believes that the evidence confirms that
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 2008, a mining engineer appointed by the court to identify
and determine the cause of environmental damage, and to specify
steps needed to remediate it, issued a report recommending that
the court assess $18.9 billion, which would, according to
the engineer, provide financial compensation for purported
damages, including wrongful death claims, and pay for, among
other items, environmental remediation, health care systems and
additional infrastructure for Petroecuador. The engineers
report also asserted that an additional $8.4 billion could
be assessed against Chevron for unjust enrichment. In 2009,
following the disclosure by Chevron of evidence that the judge
participated in meetings in which businesspeople and individuals
holding themselves out as government officials discussed the
case and its likely outcome, the judge presiding over the case
was recused. In 2010, Chevron moved to strike the mining
engineers report and to dismiss the case based on evidence
obtained through discovery in the United States indicating that
the report was prepared by consultants for the plaintiffs before
being presented as the mining engineers independent and
impartial work and showing further evidence of misconduct. In
August 2010, the judge issued an order stating that he was not
bound by the mining engineers report and requiring the
parties to provide their positions on damages within
45 days. Chevron subsequently petitioned for recusal of the
judge, claiming that he had disregarded evidence of fraud and
misconduct and that he had failed to rule on a number of motions
within the statutory time requirement.
In September 2010, Chevron submitted its position on damages,
asserting that no amount should be assessed against it. The
plaintiffs submission, which relied in part on the mining
engineers report, took the position that damages are
between approximately $16 billion and $76 billion and
that unjust enrichment should be assessed in an amount between
approximately $5 billion and $38 billion. The next
day, the judge issued an order closing the evidentiary phase of
the case and notifying the parties that he had requested the
case file so that he could prepare a judgment. Chevron
petitioned to have that order declared a nullity in light of
Chevrons prior recusal petition, and because procedural
and evidentiary matters remained unresolved. In October 2010,
Chevrons motion to recuse the judge was granted. A new
judge took charge of the case and revoked the prior judges
order closing the evidentiary phase
15
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
of the case. On December 17, 2010, the judge issued an
order closing the evidentiary phase of the case and notifying
the parties that he had requested the case file so that he could
prepare a judgment.
Chevron and Texpet filed an arbitration claim in September 2009
against the Republic of Ecuador before the Permanent Court of
Arbitration in The Hague under the Rules of the United Nations
Commission on International Trade Law. The claim alleges
violations of the Republic of Ecuadors obligations under
the United States-Ecuador Bilateral Investment Treaty (BIT) and
breaches of the settlement and release agreements between the
Republic of Ecuador and Texpet (described above), which are
investment agreements protected by the BIT. Through the
arbitration, Chevron and Texpet are seeking relief against the
Republic of Ecuador, including a declaration that any judgment
against Chevron in the Lago Agrio litigation constitutes a
violation of Ecuadors obligations under the BIT. On
February 9, 2011, the Permanent Court of Arbitration issued
an Order for Interim Measures requiring the Republic of Ecuador
to take all measures at its disposal to suspend or cause to be
suspended the enforcement or recognition within and without
Ecuador of any judgment against Chevron in the Lago Agrio case
pending further order of the Tribunal. Chevron expects to
continue seeking permanent injunctive relief and monetary relief
before the Tribunal.
Through a series of recent U.S. court proceedings initiated
by Chevron to obtain discovery relating to the Lago Agrio
litigation and the BIT arbitration, Chevron has obtained
evidence that it believes shows a pattern of fraud, collusion,
corruption, and other misconduct on the part of several lawyers,
consultants and others acting for the Lago Agrio plaintiffs. In
February 2011, Chevron filed a civil lawsuit in the Federal
District Court for the Southern District of New York against the
Lago Agrio plaintiffs and several of their lawyers, consultants
and supporters, alleging violations of the Racketeer Influenced
and Corrupt Organizations Act and other state laws. Through the
civil lawsuit, Chevron is seeking relief that includes an award
of damages and a declaration that any judgment against Chevron
in the Lago Agrio litigation is the result of fraud and other
unlawful conduct and is therefore unenforceable. On
March 7, 2011, the Federal District Court issued a
preliminary injunction prohibiting the Lago Agrio plaintiffs and
persons acting in concert with them from taking any action in
furtherance of recognition or enforcement of any judgment
against Chevron in the Lago Agrio case pending resolution of
Chevrons civil lawsuit by the Federal District Court. The
defendents appealed the preliminary injunction to the
U.S. Court of Appeals for the Second Circuit. The Federal
District Court has set a trial date of November 14, 2011
for Chevrons claim for declaratory relief.
On February 14, 2011, the Provincial Court in Lago Agrio
rendered an adverse judgment in the case. The Provincial Court
rejected Chevrons defenses to the extent the Court
addressed them in its opinion. The judgment assessed
approximately $8.6 billion in damages and approximately
$0.9 billion as an award for the plaintiffs
representatives. It also assessed an additional amount of
approximately $8.6 billion in punitive damages unless the
company issued a public apology within fifteen days of the
judgment, which Chevron did not do. On February 17, 2011,
the plaintiffs appealed the judgment, seeking increased damages,
and on March 11, 2011, Chevron appealed the judgment,
seeking to have the judgment nullified. Chevron continues to
believe the Courts judgment is illegitimate and
unenforceable in Ecuador, the United States and other countries.
The company also believes the judgment is the product of fraud,
and contrary to the legitimate scientific evidence. Chevron
cannot predict the timing or ultimate outcome of the appeals
process in Ecuador. Chevron will continue a vigorous defense of
any imposition of liability. Because Chevron has no substantial
assets in Ecuador, Chevron would expect enforcement actions as a
result of this judgment to be brought in other jurisdictions.
Chevron expects to contest any such actions.
The ultimate outcome of the foregoing matters, including any
financial effect on Chevron, remains uncertain. Management does
not believe an estimate of a reasonably possible loss (or a
range of loss) can be made in this case. Due to the defects
associated with the judgment, the 2008 engineers report
and the September 2010 plaintiffs submission, management
does not believe these documents have any utility in calculating
a reasonably possible loss (or a range of loss). Moreover, the
highly uncertain legal environment surrounding the case provides
no basis for management to estimate a reasonably possible loss
(or a range of loss).
16
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
|
|
Note 10.
|
Other
Contingencies and Commitments
|
Guarantees The company and its subsidiaries have certain
other contingent liabilities with respect to guarantees, direct
or indirect, of debt of affiliated companies or third parties.
Under the terms of the guarantee arrangements, the company would
generally be required to perform should the affiliated company
or third party fail to fulfill its obligations under the
arrangements. In some cases, the guarantee arrangements may have
recourse provisions that would enable the company to recover any
payments made under the terms of the guarantees from assets
provided as collateral.
Off-Balance-Sheet Obligations The company and its
subsidiaries have certain other contingent liabilities with
respect to long-term unconditional purchase obligations and
commitments, including throughput and
take-or-pay
agreements, some of which relate to suppliers financing
arrangements. The agreements typically provide goods and
services, such as pipeline and storage capacity, drilling rigs,
utilities, and petroleum products, to be used or sold in the
ordinary course of the 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 June 2011, the company had
paid $48 million under these indemnities and continues to
be obligated for possible additional indemnification payments in
the future.
The company has also provided indemnities relating to contingent
environmental liabilities related to assets originally
contributed by Texaco to the Equilon and Motiva joint ventures
and environmental conditions that existed prior to the formation
of Equilon and Motiva or that occurred during the period of
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.
The company posts no assets as collateral and has made no
payments under the indemnities.
The amounts payable for the indemnities described in the
preceding paragraph are to be net of amounts recovered from
insurance carriers and others and net of liabilities recorded by
Equilon or Motiva prior to September 30, 2001, for any
applicable incident.
In the acquisition of Unocal, the company assumed certain
indemnities relating to contingent environmental liabilities
associated with assets that were sold in 1997. The acquirer of
those assets shared in certain environmental remediation costs
up to a maximum obligation of $200 million, which had been
reached at December 31, 2009. Under the indemnification
agreement, after reaching the $200 million obligation,
Chevron is solely responsible until April 2022, when the
indemnification expires. The environmental conditions or events
that are subject to these indemnities must have arisen prior to
the sale of the assets in 1997.
Although the company has provided for known obligations under
this indemnity that are probable and reasonably estimable, the
amount of additional future costs may be material to results of
operations in the period in which they are recognized. The
company does not expect these costs will have a material effect
on its consolidated financial position or liquidity.
Environmental The company is subject to loss
contingencies pursuant to laws, regulations, private claims and
legal proceedings related to environmental matters that are
subject to legal settlements or that in the future may require
the company to take action to correct or ameliorate the effects
on the environment of prior release of chemicals or petroleum
substances, including MTBE, by the company or other parties.
Such contingencies may exist for various sites, including, but
not limited to, federal Superfund sites and analogous sites
under state laws, refineries, crude oil fields, service
stations, terminals, land development areas, and mining
operations, whether operating, closed or divested. These future
costs are not fully determinable due to such factors as the
unknown magnitude of possible contamination, the unknown timing
and extent of the corrective actions that may be required, the
determination of
17
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
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.
Other Contingencies On April 26, 2010, a California
appeals court issued a ruling related to the adequacy of an
Environmental Impact Report (EIR) supporting the issuance of
certain permits by the city of Richmond, California, to replace
and upgrade certain facilities at Chevrons refinery in
Richmond. Settlement discussions with plaintiffs in the case
ended late fourth quarter 2010, and on March 3, 2011, the
trial court entered a final judgment and peremptory writ
ordering the City to set aside the project EIR and conditional
use permits and enjoining Chevron from any further work. On
May 23, 2011, the company filed an application with the
City Planning Department for a conditional use permit for a
revised project to complete construction of the hydrogen plant,
certain sulfur removal facilities and related infrastructure. On
June 10, 2011, the City published its Notice of Preparation
of the revised EIR for the project. The revised and recirculated
EIR is intended to comply with the appeals court decision.
Management believes the outcomes associated with the project are
uncertain. Due to the uncertainty of the companys future
course of action, or potential outcomes of any action or
combination of actions, management does not believe an estimate
of the financial effects, if any, can be made at this time.
However, the companys ultimate exposure may be significant
to net income in any one future period.
Chevron receives claims from and submits claims to customers;
trading partners; U.S. federal, state and local regulatory
bodies; governments; contractors; insurers; and suppliers. The
amounts of these claims, individually and in the aggregate, may
be significant and take lengthy periods to resolve.
The company and its affiliates also continue to review and
analyze their operations and may close, abandon, sell, exchange,
acquire or restructure assets to achieve operational or
strategic benefits and to improve competitiveness and
profitability. These activities, individually or together, may
result in gains or losses in future periods.
|
|
Note 11.
|
Fair
Value Measurements
|
Accounting standards for fair value measurement (ASC
820) establish a framework for measuring fair value and
stipulate disclosures about fair value measurements. The
standards apply to recurring and nonrecurring fair value
measurements of financial and 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.
18
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
The fair value hierarchy for recurring assets and liabilities
measured at fair value at June 30, 2011 and
December 31, 2010, is as follows:
Assets
and Liabilities Measured at Fair Value on a Recurring Basis
(Millions of dollars)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
At June 30, 2011
|
|
At December 31, 2010
|
|
|
Total
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Total
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Marketable Securities
|
|
|
$221
|
|
|
|
$221
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$155
|
|
|
|
$155
|
|
|
|
$
|
|
|
|
$
|
|
Derivatives
|
|
|
125
|
|
|
|
9
|
|
|
|
116
|
|
|
|
|
|
|
|
122
|
|
|
|
11
|
|
|
|
111
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Assets at Fair Value
|
|
|
$346
|
|
|
|
$230
|
|
|
|
$116
|
|
|
|
$
|
|
|
|
$277
|
|
|
|
$166
|
|
|
|
$111
|
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Derivatives
|
|
|
$102
|
|
|
|
$ 63
|
|
|
|
$ 39
|
|
|
|
$
|
|
|
|
$171
|
|
|
|
$ 75
|
|
|
|
$ 96
|
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Liabilities at Fair Value
|
|
|
$102
|
|
|
|
$ 63
|
|
|
|
$ 39
|
|
|
|
$
|
|
|
|
$171
|
|
|
|
$ 75
|
|
|
|
$ 96
|
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Marketable Securities The company calculates fair value
for its marketable securities based on quoted market prices for
identical assets and liabilities. The fair values reflect the
cash that would have been received if the instruments were sold
at June 30, 2011.
Derivatives The company records its derivative
instruments other than any commodity derivative
contracts that are designated as normal purchase and normal
sale on the Consolidated Balance Sheet at fair
value, with virtually all the offsetting amount to the
Consolidated Statement of Income. For derivatives with identical
or similar provisions as contracts that are publicly traded on a
regular basis, the company uses the market values of the
publicly traded instruments as an input for fair value
calculations.
The companys derivative instruments principally include
futures, swaps, options and forward contracts for crude oil,
natural gas and refined products. Derivatives classified as
Level 1 include futures, swaps and options contracts traded
in active markets such as the New York Mercantile Exchange.
Derivatives classified as Level 2 include swaps, options,
and forward contracts principally with financial institutions
and other oil and gas companies, the fair values of which are
obtained from third-party broker quotes, industry pricing
services and exchanges. The company obtains multiple sources of
pricing information for the Level 2 instruments. Since this
pricing information is generated from observable market data, it
has historically been very consistent. The company does not
materially adjust this information. The company incorporates
internal review, evaluation and assessment procedures, including
a comparison of Level 2 fair values derived from the
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 June 30, 2011 is as follows:
Assets
and Liabilities Measured at Fair Value on a Nonrecurring
Basis
(Millions of dollars)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
At June 30, 2011
|
|
|
|
|
|
|
|
|
|
|
Before-Tax Loss
|
|
|
|
|
|
|
|
|
|
|
Three
|
|
Six
|
|
|
|
|
|
|
|
|
|
|
Months
|
|
Months
|
|
|
Total
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Ended
|
|
Ended
|
|
Properties, plant and equipment, net (held and used)
|
|
|
$42
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$42
|
|
|
|
$50
|
|
|
|
$50
|
|
Properties, plant and equipment, net (held for sale)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10
|
|
Investments and advances
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1
|
|
|
|
3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Assets at Fair Value
|
|
|
$42
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$42
|
|
|
|
$51
|
|
|
|
$63
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
19
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Impairments of Properties, plant and equipment
The company did not have any material long-lived assets
measured at fair value on a nonrecurring basis to report in the
second quarter 2011. 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. The losses on assets held for sale during
first quarter 2011 were the result of bids received from
prospective buyers.
Impairments of Investments and advances The
company did not have any material investments and advances
measured at fair value on a nonrecurring basis to report in the
second quarters 2011 and 2010. The fair values were determined
using discount rates consistent with those used by the company
to evaluate cash flows of other investments of a similar nature.
Assets and Liabilities not Required to be Measured at Fair
Value The company holds cash equivalents and bank time
deposits in U.S. and
non-U.S. portfolios.
The instruments classified as cash equivalents are primarily
bank time deposits with maturities of 90 days or less and
money market funds. Cash and cash equivalents had
carrying/fair values of $13.3 billion and
$14.1 billion at June 30, 2011 and December 31,
2010, respectively. The instruments held in Time
deposits are bank time deposits with maturities greater
than 90 days, and had carrying/fair values of
$4.4 billion and $2.9 billion at June 30, 2011
and December 31, 2010, respectively. The fair values of
cash, cash equivalents and bank time deposits reflect the cash
that would have been received if the instruments were settled at
June 30, 2011.
Cash and cash equivalents do not include investments
with a carrying/fair value of $643 million and
$855 million at June 30, 2011 and December 31,
2010, respectively. At June 30, 2011, these investments
include restricted funds related to various U.S. refinery
projects, which are reported in Deferred charges and other
assets on the Consolidated Balance Sheet. Long-term debt
of $5.6 billion at June 30, 2011 and December 31,
2010 had estimated fair values of $6.2 billion and
$6.3 billion, respectively.
The carrying values of short-term financial assets and
liabilities on the balance sheet approximate their fair values.
Fair value remeasurements of other financial instruments at
June 30, 2011 and 2010 were not material.
|
|
Note 12.
|
Derivative
Instruments and Hedging Activities
|
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
the companys financial position, results of operations or
liquidity. The company believes it has no material market or
credit risks to its operations, financial position or liquidity
as a result of its commodities and other derivatives activities.
Derivative instruments measured at fair value at June 30,
2011 and December 31, 2010, and their classification on the
Consolidated Balance Sheet and Consolidated Statement of Income
are as follows:
Consolidated
Balance Sheet: Fair Value of Derivatives Not Designated as
Hedging Instruments
(Millions of
Dollars)
|
|
|
|
|
|
|
|
|
|
|
Type of
|
|
|
|
At June 30
|
|
At December 31
|
Contract
|
|
Balance Sheet Classification
|
|
2011
|
|
2010
|
|
Commodity
|
|
Accounts and notes receivable, net
|
|
|
$ 68
|
|
|
|
$ 58
|
|
Commodity
|
|
Long-term receivables, net
|
|
|
57
|
|
|
|
64
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Assets at Fair Value
|
|
|
$ 125
|
|
|
|
$ 122
|
|
|
|
|
|
|
|
|
|
|
Commodity
|
|
Accounts payable
|
|
|
$ 70
|
|
|
|
$ 131
|
|
Commodity
|
|
Deferred credits and other noncurrent obligations
|
|
|
32
|
|
|
|
40
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Liabilities at Fair Value
|
|
|
$ 102
|
|
|
|
$ 171
|
|
|
|
|
|
|
|
|
|
|
20
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Consolidated
Statement of Income: The Effect of Derivatives Not Designated as
Hedging Instruments
(Millions of
dollars)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gain/(Loss)
|
|
|
Gain/(Loss)
|
|
|
|
|
|
Three Months Ended
|
|
|
Six Months Ended
|
|
Type of
|
|
|
|
June 30
|
|
|
June 30
|
|
Contract
|
|
Statement of Income Classification
|
|
2011
|
|
|
2010
|
|
|
2011
|
|
|
2010
|
|
|
Commodity
|
|
Sales and other operating revenues
|
|
$
|
75
|
|
|
$
|
146
|
|
|
$
|
(324
|
)
|
|
$
|
152
|
|
Commodity
|
|
Purchased crude oil and products
|
|
|
27
|
|
|
|
5
|
|
|
|
31
|
|
|
|
(26
|
)
|
Commodity
|
|
Other income
|
|
|
|
|
|
|
(9
|
)
|
|
|
(2
|
)
|
|
|
(9
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
102
|
|
|
$
|
142
|
|
|
$
|
(295
|
)
|
|
$
|
117
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note 13.
|
New
Accounting Standards
|
Fair Value Measurement (Topic 820), Amendments to Achieve
Common Fair Value Measurement and Disclosure Requirements in
U.S. GAAP and IFRS (ASU
2011-04)
In May 2011, the FASB issued ASU
2011-04,
which becomes effective for the company on January 1, 2012.
The amendments in ASU
2011-04
result in common fair value measurement and disclosure
requirements in U.S. GAAP and IFRS. As a result of these
amendments, the requirements in U.S. GAAP for measuring
fair value and for disclosing information about fair value
measurements were changed. The company does not anticipate
changes to its existing classification and measurement of fair
value when the amended standard becomes effective. However, the
companys disclosures on certain items not required to be
measured at fair value will be expanded when the amended
standard becomes effective.
Comprehensive Income (Topic 220), Presentation of
Comprehensive Income (ASU
2011-05)
The FASB issued
ASU 2011-05
in June 2011. This standard becomes effective for the company on
January 1, 2012. ASU
2011-05
changes the presentation requirements for comprehensive income.
Adoption of the standard is not expected to have a significant
impact on the companys current financial statement
presentation.
|
|
Note 14.
|
Restructuring
and Reorganization Costs
|
In the first quarter 2010, the company announced employee
reduction programs related to the restructuring and
reorganization of its downstream businesses and corporate
staffs. Total employee terminations under the programs are
currently expected to be approximately 3,100 employees.
About 1,500 of the affected employees are located in the United
States. About 2,100 employees have been terminated through
June 30, 2011, and the programs are expected to be
substantially completed by the end of 2011.
A before-tax charge of $244 million was recorded in first
quarter 2010 associated with these programs, of which
$138 million remained outstanding at December 31,
2010. During the first six months of 2011, the company made
payments of $51 million associated with these liabilities.
The majority of the payments were in Downstream. The balance at
June 30, 2011 was classified as a current liability on the
Consolidated Balance Sheet.
|
|
|
|
|
|
|
Amounts Before Tax
|
|
|
(Millions of dollars)
|
|
Balance at December 31, 2010
|
|
|
$138
|
|
Adjustment
|
|
|
(5
|
)
|
Payments
|
|
|
(51
|
)
|
|
|
|
|
|
Balance at June 30, 2011
|
|
|
$ 82
|
|
|
|
|
|
|
|
|
Note 15.
|
Assets
Held For Sale
|
At June 30, 2011, the company classified $1.4 billion
of net properties, plant and equipment as Assets held for
sale on the Consolidated Balance Sheet. These assets are
primarily associated with the companys Pembroke Refinery
and other downstream assets in the United Kingdom and Ireland,
which were divested on August 1, 2011. The
21
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
remainder reflects upstream assets that are anticipated to be
sold in 2011. The revenues and earnings contributions of these
assets in the first six months of 2011 were not material.
|
|
Note 16.
|
Acquisition
of Atlas Energy, Inc.
|
On February 17, 2011, the company acquired Atlas Energy,
Inc. (Atlas), which holds one of the premier acreage positions
in the Marcellus Shale, concentrated in southwestern
Pennsylvania. The aggregate purchase price of Atlas was
approximately $4.5 billion, which included approximately
$3.0 billion cash for all the common shares of Atlas, a
$403 million cash advance to facilitate Atlas
purchase of a 49 percent interest in Laurel Mountain
Midstream LLC and about $1.1 billion of assumed debt.
Subsequent to the close of the transaction, the company paid off
the assumed debt and made payments of $184 million in
connection with Atlas equity awards.
The acquisition was accounted for as a business combination (ASC
805) which, among other things, requires assets acquired
and liabilities assumed to be measured at their acquisition date
fair values. Provisional fair value measurements were made in
the first quarter 2011 for acquired assets and assumed
liabilities, and adjustments to those measurements may be made
in subsequent periods, up to one year from the acquisition date,
as information necessary to complete the analysis is obtained.
No adjustments to the provisional measurements were made in the
second quarter 2011. The company expects the measurement process
will be finalized by the end of 2011.
Proforma financial information is not presented as it would not
be materially different from the information presented in the
Consolidated Statement of Income.
The following table summarizes the provisional measurement of
the assets acquired and liabilities assumed:
|
|
|
|
|
|
|
At February 17, 2011
|
|
|
(Millions of dollars)
|
|
Current assets
|
|
|
$ 150
|
|
Investments and long-term receivables
|
|
|
456
|
|
Properties
|
|
|
6,051
|
|
Goodwill
|
|
|
39
|
|
Other assets
|
|
|
5
|
|
|
|
|
|
|
Total assets acquired
|
|
|
6,701
|
|
|
|
|
|
|
Current liabilities
|
|
|
(560
|
)
|
Long-term debt and capital leases
|
|
|
(761
|
)
|
Deferred income taxes
|
|
|
(1,918
|
)
|
Other liabilities
|
|
|
(25
|
)
|
|
|
|
|
|
Total liabilities assumed
|
|
|
(3,264
|
)
|
|
|
|
|
|
Net assets acquired
|
|
|
$ 3,437
|
|
|
|
|
|
|
Properties were measured primarily using an income approach. The
fair values of the acquired oil and gas properties were based on
significant inputs not observable in the market, and thus
represent Level 3 measurements. Significant inputs included
estimated resource volumes, assumed future production profiles,
estimated future commodity prices, a discount rate of
8 percent, and assumptions on the timing and amount of
future operating and development costs. All the properties are
in the United States and are included in the Upstream segment.
The acquisition date fair value of the consideration transferred
was $3.4 billion in cash. The $39 million of goodwill
was assigned to the Upstream segment and represents the amount
of the consideration transferred in excess of the values
assigned to the individual assets acquired and liabilities
assumed. Goodwill represents the future economic benefits
arising from other assets acquired that could not be
individually identified and separately recognized. None of the
goodwill is deductible for tax purposes. Goodwill recorded in
the acquisition is not subject to amortization, but will be
tested periodically for impairment as required by the applicable
accounting standard (ASC 350).
22
|
|
Item 2.
|
Managements
Discussion and Analysis of Financial Condition and Results of
Operations
|
Second
Quarter 2011 Compared with Second Quarter 2010
And Six Months 2011 Compared with Six Months 2010
Key
Financial Results
Earnings
by Business Segment
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Six Months Ended
|
|
|
|
June 30
|
|
|
June 30
|
|
|
|
2011
|
|
|
2010
|
|
|
2011
|
|
|
2010
|
|
|
|
(Millions of dollars)
|
|
|
Upstream
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
$
|
1,950
|
|
|
$
|
1,090
|
|
|
$
|
3,399
|
|
|
$
|
2,246
|
|
International
|
|
|
4,921
|
|
|
|
3,452
|
|
|
|
9,449
|
|
|
|
7,020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Upstream
|
|
|
6,871
|
|
|
|
4,542
|
|
|
|
12,848
|
|
|
|
9,266
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Downstream
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
|
564
|
|
|
|
433
|
|
|
|
1,006
|
|
|
|
515
|
|
International
|
|
|
480
|
|
|
|
542
|
|
|
|
660
|
|
|
|
656
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Downstream
|
|
|
1,044
|
|
|
|
975
|
|
|
|
1,666
|
|
|
|
1,171
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Segment Earnings
|
|
|
7,915
|
|
|
|
5,517
|
|
|
|
14,514
|
|
|
|
10,437
|
|
All Other
|
|
|
(183
|
)
|
|
|
(108
|
)
|
|
|
(571
|
)
|
|
|
(476
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income Attributable to Chevron Corporation(1)(2)
|
|
$
|
7,732
|
|
|
$
|
5,409
|
|
|
$
|
13,943
|
|
|
$
|
9,961
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) Includes foreign currency effects
|
|
$
|
(81
|
)
|
|
$
|
241
|
|
|
$
|
(245
|
)
|
|
$
|
43
|
|
(2) Also referred to as earnings in the discussions
that follow.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to Chevron Corporation for the
second quarter 2011 was $7.7 billion ($3.85 per
share diluted), compared with $5.4 billion
($2.70 per share diluted) in the corresponding 2010
period. Net income attributable to Chevron Corporation for the
first six months of 2011 was $13.9 billion ($6.94 per
share diluted), versus $9.96 billion ($4.97 per
share diluted) in the first six months of 2010.
Upstream earnings in the second quarter 2011 were
$6.9 billion, compared with $4.5 billion in the 2010
quarter. Earnings for the first six months of 2011 were
$12.8 billion, versus $9.3 billion a year earlier. The
increase between the comparative periods was mainly due to
higher crude oil realizations.
Downstream earnings were $1.0 billion in the second
quarter 2011, compared with $975 million in the
year-earlier period. Earnings for the first six months of 2011
were $1.7 billion, versus $1.2 billion in the
corresponding 2010 period. The increase between the comparative
periods was primarily associated with improved margins on
refined products, and higher earnings from chemicals
operations primarily from the 50 percent-owned
Chevron Phillips Chemical Company LLC.
Refer to pages 28 through 30 for additional discussion of
results by business segment and All Other activities
for the second quarter and first six months of 2011 versus the
same periods in 2010.
Business
Environment and Outlook
Chevron is a global energy company with substantial 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 Zone between Saudi Arabia and
Kuwait, the Philippines, Republic of the Congo, Singapore,
23
South Africa, South Korea, Thailand, Trinidad and Tobago,
the United Kingdom, the United States, Venezuela, and Vietnam.
Earnings of the company depend mostly on the profitability of
its upstream and downstream 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 other
activities and investments. Earnings for the company in any
period may also be influenced by events or transactions that are
infrequent or unusual in nature.
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 attractive 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 financial
performance and growth. Refer to the Results of
Operations section, beginning on page 28, for
discussions of net gains on asset sales during 2011. Asset
dispositions and restructurings may also occur in future periods
and could result in significant gains or losses.
In recent years, Chevron and the oil and gas industry generally
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. The company continues to actively manage its
schedule of work, contracting, procurement and supply-chain
activities to effectively manage costs.
The company closely monitors developments in the financial and
credit markets, the level of worldwide economic activity and the
implications for the company of movements in prices for crude
oil and natural gas. Management takes these developments into
account in the conduct of daily operations and for business
planning. The company remains confident of its underlying
financial strength to address potential challenges presented in
the current environment. (Refer also to the Liquidity and
Capital Resources section beginning 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,
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 seeks to manage
risks in operating its facilities and businesses. Besides the
impact of fluctuations 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.
24
Price levels for capital and exploratory costs and operating
expenses associated with the 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 can also be
affected by damage to production facilities caused by severe
weather or civil unrest.
The following chart shows the trend in benchmark prices for West
Texas Intermediate (WTI) crude oil, Brent crude oil and
U.S. Henry Hub natural gas. The WTI price averaged $79 per
barrel for the full-year 2010. During the first half of 2011,
WTI averaged $98 and ended July at $96. The Brent price averaged
$80 per barrel for the full-year 2010. During the first half of
2011, Brent averaged $111 and ended July at $117. The majority
of the companys international equity crude production is
priced based on the Brent benchmark. In recent months, due to
excess supply of WTI, Brent has traded at a premium to WTI.
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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, which is a function of the 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 widened in
the first half of 2011
|
primarily due to rising diesel prices and lower availability of
light, sweet crude oil due to supply disruptions in Libya.
Chevron produces or shares in the production of heavy crude oil
in California, Chad, Indonesia, the Partitioned Zone between
Saudi Arabia and Kuwait, Venezuela and in certain fields in
Angola, China and the United Kingdom sector of the North Sea.
(See page 33 for the companys average U.S. and
international crude oil realizations.)
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In contrast to price movements in the global market for crude
oil, price changes for natural gas in many regional markets are
more closely aligned with
supply-and-demand
conditions in those markets. In the United States, prices at
Henry Hub averaged $4.30 per thousand cubic feet (MCF) in the
first half of 2011, compared with $4.70 during the first half of
2010. At the end of July 2011, the Henry Hub spot price was
$4.26 per MCF. Fluctuations in the price for natural gas in the
United States are closely associated with customer demand
relative to the volumes produced in North America and the level
of inventory in underground storage.
Certain international natural gas markets in which the company
operates have different supply, demand and regulatory
circumstances, which historically have resulted in lower average
sales prices for the companys production of natural gas in
these locations. In some of these locations Chevron is investing
in long-term projects to install infrastructure to produce and
liquefy natural gas for transport by tanker to other markets
where prices are higher. International natural gas realizations
averaged $5.25 per MCF during the first half of 2011, compared
with $4.50 in the same period last year. (See page 33 for
the companys average natural gas realizations for the
U.S. and international regions.)
The companys worldwide net oil-equivalent production in
the first half of 2011 averaged 2.73 million barrels per
day. About one-fifth of the companys net oil-equivalent
production in the first half of 2011 occurred in the OPEC-member
countries of Angola, Nigeria, Venezuela and the Partitioned Zone
between Saudi Arabia and Kuwait. OPEC quotas had no effect on
the companys net crude oil production for the first half
of 2011 and 2010. At the latest meeting in June 2011, members of
OPEC supported maintaining production quotas in effect since
December 2008.
The company estimates that oil-equivalent production in 2011
will average 2.73 million barrels per day based on the
average Brent price of $111 per barrel for the first six months
of 2011. This estimate is subject to many factors and
uncertainties, including additional quotas that may be imposed
by OPEC, price effects on production volumes
25
calculated under production-sharing and variable-royalty
provisions of certain agreements, 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, delays in completion of
maintenance turnarounds,
greater-than-expected
declines in production from mature fields, or other disruptions
to operations. Beyond 2011, the outlook for future production
levels is also 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 made outside the United States.
Gulf of Mexico Update In May 2011, the U.S. Bureau
of Ocean Energy Management, Regulation and Enforcement (BOEMRE)
approved Chevrons permit to resume drilling operations on
the Buckskin appraisal well. BOEMRE previously approved
Chevrons revised drilling permit for the Moccasin well in
March 2011. The company has three drillships operating in the
deepwater Gulf of Mexico: one for Buckskin, one for Moccasin and
one for the Tahiti 2 development program. Additionally, in June
2011, BOEMRE approved four of Chevrons revised exploration
plan applications for projects in the deepwater Gulf of Mexico.
The future effects of the Deepwater Horizon/Macondo incident,
including any new or additional regulations that may be adopted
and the timing of BOEMRE issuing additional drilling permits,
are not fully known at this time. Chevron remains committed to
deepwater exploration and development in the Gulf of Mexico and
other deepwater basins around the world.
Refer to the Results of Operations section on pages
28 through 29 for additional discussion of the companys
upstream business.
Downstream Earnings for the downstream segment are
closely tied to margins on the refining, manufacturing and
marketing of products that include gasoline, diesel, jet fuel,
lubricants, fuel oil, fuel and lubricant additives, and
petrochemicals. Industry margins are sometimes volatile and can
be affected by the global and regional
supply-and-demand
balance for refined products and petrochemicals and by changes
in the price of crude oil, other refinery and petrochemical
feedstocks, and natural gas. Industry margins can also be
influenced by inventory levels, geopolitical events, cost of
materials and services, refinery or chemical plant capacity
utilization, maintenance programs and disruptions at refineries
or chemical plants resulting from unplanned outages 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, marketing and petrochemical assets, the effectiveness
of the crude oil and product supply functions and 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 refining,
marketing and petrochemical assets.
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. In the first half of 2011,
the companys margins improved over 2010, supported by
higher global product demand and tighter global refined product
supplies.
In first quarter 2010, the company announced that its downstream
businesses would be restructured to improve operating efficiency
and achieve sustained improvement in financial performance. As
part of this restructuring, employee-reduction programs were
announced for the United States and international downstream
operations. Approximately 2,700 employees in the downstream
operations are expected to be terminated under these programs
and substantially all will be terminated by the end of 2011.
About 1,100 of the affected employees are located in the United
States. Through second quarter 2011, 1,800 employees were
terminated worldwide. Refer to Note 14 of the Consolidated
Financial Statements, on page 21, for further discussion.
In 2010, the company solicited bids for 13 U.S. terminals
and certain operations in Europe (including the companys
Pembroke Refinery), the Caribbean, and select Central America
and Africa markets. These sales are part of the companys
ongoing effort to concentrate downstream resources and capital
on strategic, global assets. These potential market exits,
dispositions of assets, and other actions may result in gains or
losses in future periods. Through second quarter 2011, the
company completed the sale of 10 U.S. terminals, certain
marketing businesses in
26
Africa, LPG storage and distribution operations in China and its
fuels marketing and aviation businesses in 12 countries in the
Caribbean and Central America regions. In February 2011, the
company announced an agreement to sell its fuels, finished
lubricants and aviation fuels businesses in Spain. This sale is
expected to be completed in the second half 2011 pending
customary regulatory approvals. On August 1, 2011 the
company completed the sale of its 220,000-barrel-per-day
Pembroke Refinery and its fuels marketing and aviation assets in
the United Kingdom and Ireland.
Refer to the Results of Operations section on
pages 29 through 30 for additional discussion of the
companys downstream operations.
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. In first quarter 2010,
employee-reduction programs were announced for the corporate
staffs. Through the second quarter 2011, 300 employees were
terminated, and it is expected that approximately
400 employees from the corporate staffs will be terminated
under the programs by the end of 2011. Refer to Note 14 of
the Consolidated Financial Statements, on page 21, for
further discussion.
Operating
Developments
Noteworthy operating developments for the upstream business in
recent months included the following:
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Kazakhstan/Russia Marked the start of the
construction phase for expansion of the Caspian Pipeline
Consortiums pipeline, which carries crude oil from western
Kazakhstan to a dedicated terminal on the Black Sea. The design
capacity of the pipeline will increase to 1.4 million
barrels per day from its current capacity of
730,000 barrels per day. The project is planned to be
implemented in three phases, with capacity increasing
progressively from 2012 to 2015.
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Australia Received recommendation of
conditional environmental approval for the Wheatstone liquefied
natural gas (LNG) project from Western Australias
Environmental Protection Authority. The company will continue
negotiations to finalize the permit conditions as it works
toward a final investment decision on the project in the second
half of this year.
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Australia Signed binding Sales and Purchase
Agreements with Tokyo Electric for Wheatstone LNG.
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Bulgaria Awarded an exploration permit for a
prospective shale gas block of more than 1 million acres in
northeastern Bulgaria.
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United States Returned to work in the Gulf of
Mexico with three rigs active in the deepwater, drilling the
Moccasin exploration well, the Buckskin appraisal well, and the
Tahiti 2 development program. The company is also drilling on
the Gulf of Mexico Shelf to test the ultra-deep gas play.
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United States Acquired additional acreage in
the Marcellus Shale, including from Chief Oil and Gas LLC and
Tug Hill, Inc., primarily in Pennsylvania.
|
In the downstream business, the company completed the sale of
its refining, fuels marketing and aviation assets in the United
Kingdom and Ireland on August 1, 2011. The company also
completed the sale of its fuels-marketing and aviation
businesses in three Central American countries in the second
quarter 2011, as well as other assets in China and North America.
The company purchased $1 billion of its common stock in the
second quarter 2011 under its share repurchase program.
27
Results
of Operations
Business Segments The following section presents the
results of operations for the companys business
segments Upstream and Downstream as well
as for All Other. (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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Six Months Ended
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June 30
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June 30
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2011
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2010
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2011
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2010
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(Millions of dollars)
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U.S. Upstream Earnings
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$1,950
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$1,090
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$3,399
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$2,246
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U.S. upstream earnings of $1.95 billion in the second
quarter of 2011 increased $860 million from the same period
last year. The benefit of higher crude oil realizations of
$900 million was partly offset by higher operating expenses
of about $100 million.
Earnings for the first six months of 2011 were approximately
$3.40 billion, up about $1.15 billion from the
corresponding period in 2010. The benefit of higher crude oil
realizations of $1.4 billion was partly offset by the
effect of decreased net oil-equivalent production and higher
operating expenses, each about $150 million.
The companys average realization per barrel of crude oil
and natural gas liquids in the second quarter of 2011 was $104,
compared with $71 a year earlier. For the six-month periods,
average realizations were about $96 and $71 for 2011 and 2010,
respectively. The average natural gas realization in the second
quarter 2011 was $4.35 per thousand cubic feet, compared with
$4.01 in the year-ago period. The average six-month realizations
were $4.20 in 2011 and $4.66 in 2010.
Net oil-equivalent production of 694,000 barrels per day in
the second quarter 2011 was down 14,000 barrels per day, or
about 2 percent, from a year earlier. The decrease in
production was associated with normal field declines and
maintenance-related downtime. Partially offsetting this decrease
was production from the acquisition of Atlas Energy, Inc. and
increases at Perdido in the Gulf of Mexico.
First-half 2011 production was 694,000 barrels per day,
down 27,000 from the corresponding 2010 period. The decrease was
associated with normal field declines and maintenance- and
weather-related downtime. Partially offsetting this decrease was
production from the acquisition of Atlas Energy, Inc. and the
increases at Perdido in the Gulf of Mexico. The net liquids
component of oil-equivalent production was 478,000 barrels
per day and 480,000 barrels per day for the second quarter
and six months of 2011, respectively. Those volumes were
2 percent and 3 percent lower than the corresponding
2010 periods. Net natural gas production of 1.30 billion
cubic feet per day in the second quarter 2011 and
1.28 billion cubic feet per day in first half of 2011
decreased 1 percent and 5 percent from the comparative
2010 periods.
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Three Months Ended
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Six Months Ended
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June 30
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June 30
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2011
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2010
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2011
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2010
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(Millions of dollars)
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International Upstream Earnings*
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$4,921
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$3,452
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$9,449
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$7,020
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* Includes foreign currency effects
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$ 26
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$ 107
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$ (90
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$ 5
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International upstream earnings of $4.92 billion in the
second quarter 2011 increased about $1.47 billion from the
corresponding period in 2010. Higher realizations for crude oil
increased earnings by about $2.3 billion. Higher operating
expenses, including fuel, and exploration expenses decreased
earnings by about $380 million and $160 million,
respectively. Tax charges were also higher by about
$150 million between periods. Foreign currency effects
increased earnings by $26 million in the 2011 second
quarter, compared with an increase of $107 million a year
earlier.
Earnings for the first six months of 2011 were
$9.45 billion, up $2.43 billion from the same period
in 2010. Higher prices for crude oil increased earnings by
$3.9 billion. This benefit was partly offset by higher
operating expenses, including fuel, of about $700 million
and tax items of about $300 million. Higher exploration
expense further
28
reduced earnings by about $200 million. Foreign currency
effects reduced earnings by $90 million in the first six
months of 2011, compared with an increase of $5 million a
year earlier.
The average realization per barrel of crude oil and natural gas
liquids in the second quarter 2011 and six-month period were
$107 and $101, respectively, compared with $71 in the
corresponding 2010 periods. The average natural gas realization
in the 2011 second quarter was $5.49 per thousand cubic feet, up
from $4.40 in the second quarter last year. Between the
six-month periods, the average natural gas realization increased
to $5.25 from $4.50.
International net oil-equivalent production of 2.00 million
barrels per day in the second quarter 2011 decreased
38,000 barrels per day from a year ago. Production
increases from project
ramp-ups in
Canada and Brazil were more than offset by an approximately
40,000 barrels per day negative effect of higher prices on
volumes related to cost-recovery and variable-royalty
contractual provisions, and normal field declines.
International net oil-equivalent production for the six-months
of 2011 was 2.03 million barrels per day, down
10,000 barrels per day from the 2010 period. Production
increases from project
ramp-ups in
Canada and Brazil were more than offset by a 36,000 barrels
per day negative volume effect of higher prices related to
cost-recovery and variable-royalty contractual provisions, as
well as normal field declines and weather- and
maintenance-related downtime.
The net liquids component of oil-equivalent production was
1.39 million barrels per day in the second quarter 2011 and
1.41 million barrels per day in the six-month period,
decreases of 2 and 1 percent for the respective periods.
Net natural gas production totaled 3.67 billion cubic feet
per day in the second quarter 2011 and 3.75 billion cubic
feet per day in the first six months, a decrease of
1 percent and an increase of 1 percent, from the
respective 2010 periods.
Downstream
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Three Months Ended
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Six Months Ended
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June 30
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June 30
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2011
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2010
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2011
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2010
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(Millions of dollars)
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U.S. Downstream Earnings
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$564
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$433
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$1,006
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$515
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U.S. downstream earned $564 million in the second
quarter 2011, compared with earnings of $433 million a year
earlier. Earnings for the first six months of 2011 were
$1.01 billion, compared with $515 million in the same
period of 2010. Improved margins on refined products benefited
earnings by $80 million and $340 million in the second
quarter and the six months in 2011, respectively. Higher
earnings from the 50 percent-owned Chevron Phillips
Chemical Company LLC (CPChem) also increased earnings by
$60 million and $140 million in the comparative
periods, respectively.
Refinery crude-input of 875,000 barrels per day in the
second quarter 2011 decreased 42,000 barrels per day from
the year-ago period. Inputs of 877,000 barrels per day for
the six months of 2011 decreased about 3 percent from the
corresponding 2010 period.
Refined product sales of 1.27 million barrels per day for
the quarterly period and 1.28 million barrels per day for
the six-month period of 2011 declined 10 percent and
8 percent, respectively. The declines were mainly due to
lower gasoline and jet fuel sales for both periods. Branded
gasoline sales of 510,000 and 506,000 barrels per day for
the second quarter and six months in 2011 decreased
16 percent and 15 percent, respectively, largely due
to previously completed exits from selected eastern
U.S. retail markets.
29
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Three Months Ended
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Six Months Ended
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June 30
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June 30
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2011
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2010
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2011
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2010
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(Millions of dollars)
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International Downstream Earnings*
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$480
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$542
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$ 660
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$656
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* Includes foreign currency effects.
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$(94
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)
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$131
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$(132
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$ 35
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International downstream operations earned $480 million in
the second quarter 2011, compared with $542 million a year
earlier. Improved margins on refined products benefited earnings
by $200 million. However, foreign currency effects
decreased earnings by $94 million in the 2011 quarter,
compared with an increase of $131 million a year earlier.
Earnings for the first six months of 2011 were
$660 million, compared with $656 million in the
corresponding 2010 period. Higher margins benefited earnings by
$250 million. Also contributing to earnings were gains on
asset sales of $160 million and the absence of 2010 charges
of $100 million related to employee reductions. These
benefits were partly offset by unfavorable effects of derivative
instruments of about $300 million. Foreign currency effects
decreased earnings by $132 million in 2011, compared with a
benefit of $35 million a year earlier.
Refinery crude-input of 1.02 million barrels per day in the
2011 second quarter increased 63,000 barrels per day from
second quarter 2010. For the six months of 2011, crude oil
inputs were 1.02 million barrels per day, up
51,000 barrels per day from the year-ago period. The
increase for both comparative periods was attributable mainly to
the absence of 2010 planned and unplanned refinery downtime.
Total refined product sales of 1.83 million barrels per day
for the quarterly period and 1.81 million barrels per day
for the first six months of 2011 were both 3 percent higher
than a year earlier, mainly due to higher sales of fuel oil.
All
Other
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Three Months Ended
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Six Months Ended
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June 30
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June 30
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2011
|
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2010
|
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2011
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2010
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(Millions of dollars)
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Net Charges*
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|
|
$(183
|
)
|
|
|
$(108
|
)
|
|
|
$(571
|
)
|
|
|
$(476
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* Includes foreign currency effects
|
|
|
$ (13
|
)
|
|
|
$ 3
|
|
|
|
$ (23
|
)
|
|
|
$ 3
|
|
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 second quarter 2011 were $183 million,
compared with $108 million in the year-ago period. The
change between periods was mainly due to higher corporate tax
charges and employee compensation and benefit expenses. Foreign
currency effects increased net charges by $13 million in
the 2011 second quarter, compared with a $3 million
reduction in net charges last year. For the six months of 2011,
net charges were $571 million, compared with
$476 million a year earlier. Net charges for employee
compensation and benefits were higher in the 2011 six-month
period. Foreign currency effects increased net charges by
$23 million for the six months of 2011, compared with a
$3 million reduction in net charges last year.
30
Consolidated
Statement of Income
Explanations of variations between periods for certain income
statement categories are provided below:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
June 30
|
|
June 30
|
|
|
2011
|
|
2010
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Sales and other operating revenues
|
|
|
$66,671
|
|
|
|
$51,051
|
|
|
|
$125,083
|
|
|
|
$97,792
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Sales and other operating revenues for the quarterly and
six-month periods increased $16 billion and
$27 billion, respectively, mainly due to higher prices for
crude oil, natural gas and refined products.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
June 30
|
|
June 30
|
|
|
2011
|
|
2010
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Income from equity affiliates
|
|
|
$1,882
|
|
|
|
$1,650
|
|
|
|
$3,569
|
|
|
|
$2,885
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from equity affiliates increased between the quarterly
and six-month periods mainly due to higher upstream-related
earnings from Tengizchevroil in Kazakhstan as a result of higher
prices for crude oil, partly offset by an unfavorable swing in
foreign currency effects at GS Caltex in South Korea.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
June 30
|
|
June 30
|
|
|
2011
|
|
2010
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Other income
|
|
|
$ 395
|
|
|
|
$ 303
|
|
|
|
$ 637
|
|
|
|
$ 506
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income for the quarterly and six month periods increased
mainly due to higher gains on asset sales, partially offset by
an unfavorable swing in foreign currency effects.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
June 30
|
|
June 30
|
|
|
2011
|
|
2010
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Purchased crude oil and products
|
|
|
$40,759
|
|
|
|
$30,604
|
|
|
|
$75,960
|
|
|
|
$57,748
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Purchases increased $10 billion and $18 billion in the
quarterly and six-month periods mainly due to higher prices for
crude oil and refined products.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
June 30
|
|
June 30
|
|
|
2011
|
|
2010
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Operating, selling, general and
administrative expenses
|
|
|
$6,460
|
|
|
|
$5,727
|
|
|
|
$12,623
|
|
|
|
$11,358
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating, selling, general and administrative expenses
increased $733 million between quarters and
$1.27 billion between the six-month periods. Higher
expenses were primarily related to fuel and employee
compensation and benefits. These accounted for approximately
$770 million and $1.3 billion of the increase between
the quarterly and six-month periods, respectively. Increased
fuel purchases reflected a new commercial arrangement that
replaced a prior product exchange agreement for Upstream
operations in Indonesia.
31
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
June 30
|
|
June 30
|
|
|
2011
|
|
2010
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Exploration expenses
|
|
|
$ 422
|
|
|
|
$ 212
|
|
|
|
$ 590
|
|
|
|
$ 392
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The increase in exploration expenses between quarterly and
six-month periods was primarily due to higher amounts for well
write-offs and geological and geophysical costs.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
June 30
|
|
June 30
|
|
|
2011
|
|
2010
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Depreciation, depletion and amortization
|
|
|
$3,257
|
|
|
|
$3,142
|
|
|
|
$6,383
|
|
|
|
$6,223
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The increase in the second quarter and six-month periods mainly
reflected higher depreciation rates for certain oil and gas
producing fields, increased accretion expense associated with
higher asset retirement obligations, as well as higher upstream
impairments.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
June 30
|
|
June 30
|
|
|
2011
|
|
2010
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Taxes other than on income
|
|
|
$4,843
|
|
|
|
$4,537
|
|
|
|
$9,404
|
|
|
|
$9,009
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Taxes other than on income increased primarily due to higher
export duties in the companys South Africa downstream
operations and higher excise taxes in the companys China
upstream operations.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
June 30
|
|
June 30
|
|
|
2011
|
|
2010
|
|
2011
|
|
2010
|
|
|
(Millions of dollars)
|
|
Income tax expense
|
|
|
$5,447
|
|
|
|
$3,322
|
|
|
|
$10,330
|
|
|
|
$6,392
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effective income tax rates for the 2011 and 2010 second quarters
were 41 percent and 38 percent, respectively. For the
year-to-date
periods, the effective tax rates were 42 and 39 percent,
respectively. The increase in the overall effective tax rates in
both the quarterly and six-month comparisons primarily reflected
higher effective tax rates in international upstream operations.
For both comparative periods, the higher international upstream
effective tax rates were driven primarily by a reduced effect of
non-U.S. tax
benefits and increased withholding taxes in the current year
periods. Additionally, for the quarterly comparison, foreign
currency remeasurement impacts caused an increase in the
effective tax rate.
32
Selected
Operating Data
The following table presents a comparison of selected operating
data:
Selected
Operating Data(1)(2)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Six Months Ended
|
|
|
|
June 30
|
|
|
June 30
|
|
|
|
2011
|
|
|
2010
|
|
|
2011
|
|
|
2010
|
|
|
U.S. Upstream
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net crude oil and natural gas liquids production (MBPD)
|
|
|
478
|
|
|
|
488
|
|
|
|
480
|
|
|
|
496
|
|
Net natural gas production (MMCFPD)(3)
|
|
|
1,299
|
|
|
|
1,317
|
|
|
|
1,284
|
|
|
|
1,347
|
|
Net oil-equivalent production (MBOEPD)
|
|
|
694
|
|
|
|
708
|
|
|
|
694
|
|
|
|
721
|
|
Sales of natural gas (MMCFPD)
|
|
|
5,724
|
|
|
|
5,770
|
|
|
|
5,744
|
|
|
|
5,888
|
|
Sales of natural gas liquids (MBPD)
|
|
|
10
|
|
|
|
27
|
|
|
|
15
|
|
|
|
24
|
|
Revenue from net production
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liquids ($/Bbl)
|
|
$
|
103.63
|
|
|
$
|
70.69
|
|
|
$
|
96.39
|
|
|
$
|
70.61
|
|
Natural gas ($/MCF)
|
|
$
|
4.35
|
|
|
$
|
4.01
|
|
|
$
|
4.20
|
|
|
$
|
4.66
|
|
International Upstream
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net crude oil and natural gas liquids production (MBPD)(4)
|
|
|
1,388
|
|
|
|
1,422
|
|
|
|
1,408
|
|
|
|
1,425
|
|
Net natural gas production (MMCFPD)(3)
|
|
|
3,670
|
|
|
|
3,699
|
|
|
|
3,748
|
|
|
|
3,711
|
|
Net oil-equivalent production (MBOEPD)(3)(4)
|
|
|
2,000
|
|
|
|
2,038
|
|
|
|
2,033
|
|
|
|
2,043
|
|
Sales of natural gas (MMCFPD)
|
|
|
4,386
|
|
|
|
4,740
|
|
|
|
4,412
|
|
|
|
4,430
|
|
Sales of natural gas liquids (MBPD)
|
|
|
23
|
|
|
|
29
|
|
|
|
24
|
|
|
|
28
|
|
Revenue from liftings
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liquids ($/Bbl)
|
|
$
|
106.84
|
|
|
$
|
71.44
|
|
|
$
|
100.99
|
|
|
$
|
70.75
|
|
Natural gas ($/MCF)
|
|
$
|
5.49
|
|
|
$
|
4.40
|
|
|
$
|
5.25
|
|
|
$
|
4.50
|
|
U.S. and International Upstream
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total net oil-equivalent production (MBOEPD)(3)(4)
|
|
|
2,694
|
|
|
|
2,746
|
|
|
|
2,727
|
|
|
|
2,764
|
|
U.S. Downstream
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gasoline sales (MBPD)(5)
|
|
|
655
|
|
|
|
737
|
|
|
|
653
|
|
|
|
726
|
|
Other refined product sales (MBPD)
|
|
|
614
|
|
|
|
670
|
|
|
|
622
|
|
|
|
652
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total refined product sales (MBPD)
|
|
|
1,269
|
|
|
|
1,407
|
|
|
|
1,275
|
|
|
|
1,378
|
|
Sales of natural gas liquids (MBPD)
|
|
|
152
|
|
|
|
144
|
|
|
|
145
|
|
|
|
141
|
|
Refinery input (MBPD)
|
|
|
875
|
|
|
|
917
|
|
|
|
877
|
|
|
|
903
|
|
International Downstream
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gasoline sales (MBPD)(5)
|
|
|
374
|
|
|
|
440
|
|
|
|
388
|
|
|
|
413
|
|
Other refined product sales (MBPD)
|
|
|
882
|
|
|
|
794
|
|
|
|
844
|
|
|
|
796
|
|
Share of affiliate sales (MBPD)
|
|
|
572
|
|
|
|
541
|
|
|
|
574
|
|
|
|
542
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total refined product sales (MBPD)
|
|
|
1,828
|
|
|
|
1,775
|
|
|
|
1,806
|
|
|
|
1,751
|
|
Sales of natural gas liquids (MBPD)
|
|
|
68
|
|
|
|
74
|
|
|
|
67
|
|
|
|
75
|
|
Refinery input (MBPD)
|
|
|
1,017
|
|
|
|
954
|
|
|
|
1,024
|
|
|
|
973
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(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 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
|
|
|
76
|
|
|
|
63
|
|
|
|
71
|
|
|
|
65
|
|
International
|
|
|
475
|
|
|
|
431
|
|
|
|
487
|
|
|
|
460
|
|
(4) Includes: Canada synthetic oil
|
|
|
41
|
|
|
|
16
|
|
|
|
38
|
|
|
|
20
|
|
Venezuela affiliate synthetic oil
|
|
|
31
|
|
|
|
29
|
|
|
|
31
|
|
|
|
29
|
|
(5) Includes branded and unbranded gasoline.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
33
Liquidity
and Capital Resources
Cash, cash equivalents, time deposits and marketable
securities totaled approximately $18.0 billion at
June 30, 2011, up $0.9 billion from year-end 2010.
Cash provided by operating activities in the first six months of
2011 was $20.5 billion, compared with $15.1 billion in
the year-ago period. Cash provided by operating activities
during the first half of 2011 was more than sufficient to fund
the companys $12.8 billion capital and exploratory
program, pay $3 billion of dividends to shareholders and
repurchase $1.75 billion of common stock. In addition, the
company completed the $4.5 billion acquisition of Atlas
Energy, Inc., primarily funded from the companys operating
cash flows.
Dividends The company paid dividends of $3.0 billion
to common stockholders during the first six months of 2011. In
July 2011, the company declared a quarterly dividend of 78 cents
per common share payable in September 2011.
Debt and Capital Lease Obligations Chevrons total
debt and capital lease obligations were $11.5 billion at
both June 30, 2011 and December 31, 2010.
In July 2011, the company called $1.5 billion of bonds due
to mature in March 2012.
The companys debt and capital lease obligations due within
one year, consisting primarily of commercial paper, redeemable
long-term obligations and the current portion of long-term debt,
totaled $7.3 billion at June 30, 2011 and $5.6 at
December 31, 2010. Of this amount, $5.4 billion was
reclassified to long-term at both June 30, 2011 and
December 31, 2010. At June 30, 2011, settlement of
these obligations was not expected to require the use of working
capital within one year, as the company had the intent and the
ability, as evidenced by committed credit facilities, to
refinance them on a long-term basis.
At June 30, 2011, the company had $6.0 billion in
committed credit facilities with various major banks, expiring
in May 2013, which enable the refinancing of short-term
obligations on a long-term basis. These facilities support
commercial paper borrowing and can also 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 (LIBOR) 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 June 30, 2011. In
addition, the company has an automatic shelf registration
statement that expires in March 2013 for an unspecified amount
of nonconvertible debt securities issued or guaranteed by the
company.
The major debt rating agencies routinely evaluate the
companys debt, and the companys cost of borrowing
can increase or decrease depending on these debt ratings. The
company has outstanding public bonds issued by Chevron
Corporation, Chevron Corporation Profit Sharing/Savings Plan
Trust Fund, and Texaco Capital Inc. 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 program and cash that may be
generated from asset dispositions. Based on its high-quality
debt ratings, the company believes that it has substantial
borrowing capacity to meet unanticipated cash requirements. The
company also can modify capital spending plans during periods of
low prices for crude oil and natural gas and narrow margins for
refined products and commodity chemicals to provide flexibility
to continue paying the common stock dividend and maintain the
companys high-quality debt ratings.
Common Stock Repurchase Program In July 2010, the Board
of Directors approved an ongoing share repurchase program with
no set term or monetary limits. The company expects to
repurchase between $500 million and $2 billion of its
common shares per quarter, at prevailing prices, as permitted by
securities laws and other legal requirements and subject to
market conditions and other factors. During second quarter 2011,
the company purchased 9.7 million common shares for
$1 billion. From the inception of the program through
second quarter 2011, the company had purchased 26.1 million
shares for $2.5 billion.
Noncontrolling Interests The company had noncontrolling
interests of $777 million and $730 million at
June 30, 2011 and December 31, 2010, respectively.
Distributions to noncontrolling interests totaled
$28 million during the first six months of 2011.
34
Current Ratio current assets divided by
current liabilities, which indicates the companys ability
to repay its short-term liabilities with short-term assets. The
current ratio was 1.5 at June 30, 2011, and 1.7 at
December 31, 2010. The current ratio is adversely affected
by the fact that Chevrons inventories are valued on a
last-in,
first-out basis. At June 30, 2011, the book value of
inventory was lower than replacement costs.
Debt Ratio total debt as a percentage of
total debt plus Chevron Corporation Stockholders Equity,
which indicates the companys leverage. This ratio was
9.1 percent at June 30, 2011, and 9.8 percent at
year-end 2010.
Pension Obligations At the end of 2010, the company
estimated it would contribute $950 million to employee
pension plans during 2011 (composed of $650 million for the
U.S. plans and $300 million for the international
plans). Through June 30, 2011, a total of $557 million
was contributed (including $374 million to the
U.S. plans). In July 2011, the company contributed
$750 million to the U.S. plans. Total contributions
for the full year are currently estimated to be
$1.45 billion ($1.15 billion for the U.S. plans
and $300 million for the international plans). Actual
contribution amounts are dependent upon plan investment returns,
changes in pension obligations, regulatory environments and
other economic factors. Additional funding may ultimately be
required if investment returns are insufficient to offset
increases in plan obligations.
Capital and Exploratory Expenditures Total expenditures,
including the companys share of spending by affiliates,
were $13.4 billion in the first six months of 2011,
compared with $9.4 billion in the corresponding 2010
period. The amounts included the companys share of
affiliates expenditures of about $600 million in both
the 2011 and 2010 periods, respectively. Expenditures for
upstream projects in the first six months of 2011 were about
$12.1 billion, representing 91 percent of the
companywide total.
Capital
and Exploratory Expenditures by Major Operating Area
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Six Months Ended
|
|
|
|
June 30
|
|
|
June 30
|
|
|
|
2011
|
|
|
2010
|
|
|
2011
|
|
|
2010
|
|
|
|
(Millions of dollars)
|
|
|
United States
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream
|
|
$
|
3,298
|
|
|
$
|
679
|
|
|
$
|
4,281
|
|
|
$
|
1,532
|
|
Downstream
|
|
|
301
|
|
|
|
331
|
|
|
|
532
|
|
|
|
603
|
|
All Other
|
|
|
310
|
|
|
|
68
|
|
|
|
346
|
|
|
|
102
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total United States
|
|
|
3,909
|
|
|
|
1,078
|
|
|
|
5,159
|
|
|
|
2,237
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
International
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Upstream
|
|
|
4,187
|
|
|
|
3,743
|
|
|
|
7,861
|
|
|
|
6,772
|
|
Downstream
|
|
|
245
|
|
|
|
218
|
|
|
|
366
|
|
|
|
412
|
|
All Other
|
|
|
2
|
|
|
|
4
|
|
|
|
3
|
|
|
|
4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total International
|
|
|
4,434
|
|
|
|
3,965
|
|
|
|
8,230
|
|
|
|
7,188
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Worldwide
|
|
$
|
8,343
|
|
|
$
|
5,043
|
|
|
$
|
13,389
|
|
|
$
|
9,425
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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 20 pending lawsuits and
claims, the majority of which involve numerous other petroleum
marketers and refiners. Resolution of these lawsuits and claims
may ultimately require the company to correct or ameliorate the
alleged effects on the environment of prior release of MTBE by
the company or other parties. Additional lawsuits and claims
related to the use of MTBE, including personal-injury claims,
may be filed in the future. The companys ultimate exposure
related to pending lawsuits and claims is not determinable, but
could be material to net income in any one period. The company
no longer uses MTBE in the manufacture of gasoline in the United
States.
Ecuador Chevron is a defendant in a civil lawsuit before
the Superior Court of Nueva Loja in Lago Agrio, Ecuador, brought
in May 2003 by plaintiffs who claim to be representatives of
certain residents of an area where an oil production consortium
formerly had operations. The lawsuit alleges damage to the
environment from the oil
35
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; third,
that the claims are barred by the statute of limitations in
Ecuador; and, fourth, that the lawsuit is also barred by the
releases from liability previously given to Texpet by the
Republic of Ecuador and Petroecuador and by the pertinent
provincial and municipal governments. With regard to the facts,
the company believes that the evidence confirms that
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 2008, a mining engineer appointed by the court to identify
and determine the cause of environmental damage, and to specify
steps needed to remediate it, issued a report recommending that
the court assess $18.9 billion, which would, according to
the engineer, provide financial compensation for purported
damages, including wrongful death claims, and pay for, among
other items, environmental remediation, health care systems and
additional infrastructure for Petroecuador. The engineers
report also asserted that an additional $8.4 billion could
be assessed against Chevron for unjust enrichment. In 2009,
following the disclosure by Chevron of evidence that the judge
participated in meetings in which businesspeople and individuals
holding themselves out as government officials discussed the
case and its likely outcome, the judge presiding over the case
was recused. In 2010, Chevron moved to strike the mining
engineers report and to dismiss the case based on evidence
obtained through discovery in the United States indicating that
the report was prepared by consultants for the plaintiffs before
being presented as the mining engineers independent and
impartial work and showing further evidence of misconduct. In
August 2010, the judge issued an order stating that he was not
bound by the mining engineers report and requiring the
parties to provide their positions on damages within
45 days. Chevron subsequently petitioned for recusal of the
judge, claiming that he had disregarded evidence of fraud and
misconduct and that he had failed to rule on a number of motions
within the statutory time requirement.
In September 2010, Chevron submitted its position on damages,
asserting that no amount should be assessed against it. The
plaintiffs submission, which relied in part on the mining
engineers report, took the position that damages are
between approximately $16 billion and $76 billion and
that unjust enrichment should be assessed in an amount between
approximately $5 billion and $38 billion. The next
day, the judge issued an order closing the evidentiary phase of
the case and notifying the parties that he had requested the
case file so that he could prepare a judgment. Chevron
petitioned to have that order declared a nullity in light of
Chevrons prior recusal petition, and because procedural
and evidentiary matters remained unresolved. In October 2010,
Chevrons motion to recuse the judge was granted. A new
judge took charge of the case and revoked the prior judges
order closing the evidentiary phase of the case. On
December 17, 2010, the judge issued an order closing the
evidentiary phase of the case and notifying the parties that he
had requested the case file so that he could prepare a judgment.
Chevron and Texpet filed an arbitration claim in September 2009
against the Republic of Ecuador before the Permanent Court of
Arbitration in The Hague under the Rules of the United Nations
Commission on International Trade Law. The claim alleges
violations of the Republic of Ecuadors obligations under
the United States-Ecuador Bilateral Investment Treaty (BIT) and
breaches of the settlement and release agreements between the
Republic of Ecuador and Texpet (described above), which are
investment agreements protected by the BIT. Through the
arbitration, Chevron and Texpet are seeking relief against the
Republic of Ecuador, including a declaration that any judgment
against Chevron in the Lago Agrio litigation constitutes a
violation of Ecuadors obligations under the
36
BIT. On February 9, 2011, the Permanent Court of
Arbitration issued an Order for Interim Measures requiring the
Republic of Ecuador to take all measures at its disposal to
suspend or cause to be suspended the enforcement or recognition
within and without Ecuador of any judgment against Chevron in
the Lago Agrio case pending further order of the Tribunal.
Chevron expects to continue seeking permanent injunctive relief
and monetary relief before the Tribunal.
Through a series of recent U.S. court proceedings initiated
by Chevron to obtain discovery relating to the Lago Agrio
litigation and the BIT arbitration, Chevron has obtained
evidence that it believes shows a pattern of fraud, collusion,
corruption, and other misconduct on the part of several lawyers,
consultants and others acting for the Lago Agrio plaintiffs. In
February 2011, Chevron filed a civil lawsuit in the Federal
District Court for the Southern District of New York against the
Lago Agrio plaintiffs and several of their lawyers, consultants
and supporters, alleging violations of the Racketeer Influenced
and Corrupt Organizations Act and other state laws. Through the
civil lawsuit, Chevron is seeking relief that includes an award
of damages and a declaration that any judgment against Chevron
in the Lago Agrio litigation is the result of fraud and other
unlawful conduct and is therefore unenforceable. On
March 7, 2011, the Federal District Court issued a
preliminary injunction prohibiting the Lago Agrio plaintiffs and
persons acting in concert with them from taking any action in
furtherance of recognition or enforcement of any judgment
against Chevron in the Lago Agrio case pending resolution of
Chevrons civil lawsuit by the Federal District Court. The
defendents appealed the preliminary injunction to the
U.S. Court of Appeals for the Second Circuit. The Federal
District Court has set a trial date of November 14, 2011
for Chevrons claim for declaratory relief.
On February 14, 2011, the Provincial Court in Lago Agrio
rendered an adverse judgment in the case. The Provincial Court
rejected Chevrons defenses to the extent the Court
addressed them in its opinion. The judgment assessed
approximately $8.6 billion in damages and approximately
$0.9 billion as an award for the plaintiffs
representatives. It also assessed an additional amount of
approximately $8.6 billion in punitive damages unless the
company issued a public apology within fifteen days of the
judgment, which Chevron did not do. On February 17, 2011,
the plaintiffs appealed the judgment, seeking increased damages,
and on March 11, 2011, Chevron appealed the judgment,
seeking to have the judgment nullified. Chevron continues to
believe the Courts judgment is illegitimate and
unenforceable in Ecuador, the United States and other countries.
The company also believes the judgment is the product of fraud,
and contrary to the legitimate scientific evidence. Chevron
cannot predict the timing or ultimate outcome of the appeals
process in Ecuador. Chevron will continue a vigorous defense of
any imposition of liability. Because Chevron has no substantial
assets in Ecuador, Chevron would expect enforcement actions as a
result of this judgment to be brought in other jurisdictions.
Chevron expects to contest any such actions.
The ultimate outcome of the foregoing matters, including any
financial effect on Chevron, remains uncertain. Management does
not believe an estimate of a reasonably possible loss (or a
range of loss) can be made in this case. Due to the defects
associated with the judgment, the 2008 engineers report
and the September 2010 plaintiffs submission, management
does not believe these documents have any utility in calculating
a reasonably possible loss (or a range of loss). Moreover, the
highly uncertain legal environment surrounding the case provides
no basis for management to estimate a reasonably possible loss
(or a range of loss).
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, the company would
generally be required to perform should the affiliated company
or third party fail to fulfill its obligations under the
arrangements. In some cases, the guarantee arrangements may have
recourse provisions that would enable the company to recover any
payments made under the terms of the guarantees from assets
provided as collateral.
Off-Balance-Sheet Obligations The company and its
subsidiaries have certain other contingent liabilities with
respect to long-term unconditional purchase obligations and
commitments, including throughput and
take-or-pay
agreements, some of which relate to suppliers financing
arrangements. The agreements typically provide goods and
services, such as pipeline and storage capacity, drilling rigs,
utilities, and petroleum products, to be used or sold in the
ordinary course of the 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.
37
The company would be required to perform if the indemnified
liabilities become actual losses. Were that to occur, the
company could be required to make future payments up to
$300 million. Through the end of June 2011, the company had
paid $48 million under these indemnities and continues to
be obligated for possible additional indemnification payments in
the future.
The company has also provided indemnities relating to contingent
environmental liabilities related to assets originally
contributed by Texaco to the Equilon and Motiva joint ventures
and environmental conditions that existed prior to the formation
of Equilon and Motiva or that occurred during the period of
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.
The company posts no assets as collateral and has made no
payments under the indemnities.
The amounts payable for the indemnities described in the
preceding paragraph are to be net of amounts recovered from
insurance carriers and others and net of liabilities recorded by
Equilon or Motiva prior to September 30, 2001, for any
applicable incident.
In the acquisition of Unocal, the company assumed certain
indemnities relating to contingent environmental liabilities
associated with assets that were sold in 1997. The acquirer of
those assets shared in certain environmental remediation costs
up to a maximum obligation of $200 million, which had been
reached at December 31, 2009. Under the indemnification
agreement, after reaching the $200 million obligation,
Chevron is solely responsible until April 2022, when the
indemnification expires. The environmental conditions or events
that are subject to these indemnities must have arisen prior to
the sale of the assets in 1997.
Although the company has provided for known obligations under
this indemnity that are probable and reasonably estimable, the
amount of additional future costs may be material to results of
operations in the period in which they are recognized. The
company does not expect these costs will have a material effect
on its consolidated financial position or liquidity.
Environmental The company is subject to loss
contingencies pursuant to laws, regulations, private claims and
legal proceedings related to environmental matters that are
subject to legal settlements or that in the future may require
the company to take action to correct or ameliorate the effects
on the environment of prior release of chemicals or petroleum
substances, including MTBE, by the company or other parties.
Such contingencies may exist for various sites, including, but
not limited to, federal Superfund sites and analogous sites
under state laws, refineries, crude oil fields, service
stations, terminals, land development areas, and mining
operations, whether operating, closed or divested. These future
costs are not fully determinable due to such factors as the
unknown magnitude of possible contamination, the unknown timing
and extent of the corrective actions that may be required, the
determination of the 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.
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
June 30, 2011. For these jurisdictions, the latest years
for which income tax examinations had been finalized were as
follows: United States 2007, Nigeria
2000, 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
38
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 On April 26, 2010, a California
appeals court issued a ruling related to the adequacy of an
Environmental Impact Report (EIR) supporting the issuance of
certain permits by the city of Richmond, California, to replace
and upgrade certain facilities at Chevrons refinery in
Richmond. Settlement discussions with plaintiffs in the case
ended late fourth quarter 2010, and on March 3, 2011, the
trial court entered a final judgment and peremptory writ
ordering the City to set aside the project EIR and conditional
use permits and enjoining Chevron from any further work. On
May 23, 2011, the company filed an application with the
City Planning Department for a conditional use permit for a
revised project to complete construction of the hydrogen plant,
certain sulfur removal facilities and related infrastructure. On
June 10, 2011, the City published its Notice of Preparation
of the revised EIR for the project. The revised and recirculated
EIR is intended to comply with the appeals court decision.
Management believes the outcomes associated with the project are
uncertain. Due to the uncertainty of the companys future
course of action, or potential outcomes of any action or
combination of actions, management does not believe an estimate
of the financial effects, if any, can be made at this time.
However, the companys ultimate exposure may be significant
to net income in any one future period.
Chevron receives claims from and submits claims to customers;
trading partners; U.S. federal, state and local regulatory
bodies; governments; contractors; insurers; and suppliers. The
amounts of these claims, individually and in the aggregate, may
be significant and take lengthy periods to resolve.
The company and its affiliates also continue to review and
analyze their operations and may close, abandon, sell, exchange,
acquire or restructure assets to achieve operational or
strategic benefits and to improve competitiveness and
profitability. These activities, individually or together, may
result in gains or losses in future periods.
New
Accounting Standards
Refer to Note 13, on page 21 in the Notes to
Consolidated Financial Statements, for information regarding new
accounting standards.
|
|
Item 3.
|
Quantitative
and Qualitative Disclosures About Market Risk
|
Information about market risks for the three months ended
June 30, 2011, does not differ materially from that
discussed under Item 7A of Chevrons 2010 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 June 30, 2011.
(b) Changes in internal control over financial reporting
During the quarter ended June 30, 2011, there were no
changes in the companys internal control over financial
reporting that have materially affected, or are reasonably
likely to materially affect, the companys internal control
over financial reporting.
39
PART II
OTHER
INFORMATION
|
|
Item 1.
|
Legal
Proceedings
|
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; third,
that the claims are barred by the statute of limitations in
Ecuador; and, fourth, that the lawsuit is also barred by the
releases from liability previously given to Texpet by the
Republic of Ecuador and Petroecuador and by the pertinent
provincial and municipal governments. With regard to the facts,
the company believes that the evidence confirms that
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 2008, a mining engineer appointed by the court to identify
and determine the cause of environmental damage, and to specify
steps needed to remediate it, issued a report recommending that
the court assess $18.9 billion, which would, according to
the engineer, provide financial compensation for purported
damages, including wrongful death claims, and pay for, among
other items, environmental remediation, health care systems and
additional infrastructure for Petroecuador. The engineers
report also asserted that an additional $8.4 billion could
be assessed against Chevron for unjust enrichment. In 2009,
following the disclosure by Chevron of evidence that the judge
participated in meetings in which businesspeople and individuals
holding themselves out as government officials discussed the
case and its likely outcome, the judge presiding over the case
was recused. In 2010, Chevron moved to strike the mining
engineers report and to dismiss the case based on evidence
obtained through discovery in the United States indicating that
the report was prepared by consultants for the plaintiffs before
being presented as the mining engineers independent and
impartial work and showing further evidence of misconduct. In
August 2010, the judge issued an order stating that he was not
bound by the mining engineers report and requiring the
parties to provide their positions on damages within
45 days. Chevron subsequently petitioned for recusal of the
judge, claiming that he had disregarded evidence of fraud and
misconduct and that he had failed to rule on a number of motions
within the statutory time requirement.
In September 2010, Chevron submitted its position on damages,
asserting that no amount should be assessed against it. The
plaintiffs submission, which relied in part on the mining
engineers report, took the position that damages are
between approximately $16 billion and $76 billion and
that unjust enrichment should be assessed in an amount between
approximately $5 billion and $38 billion. The next
day, the judge issued an order closing the evidentiary phase of
the case and notifying the parties that he had requested the
case file so that he could prepare a judgment. Chevron
petitioned to have that order declared a nullity in light of
Chevrons prior recusal petition, and because procedural
and evidentiary matters remained unresolved. In October 2010,
Chevrons motion to recuse the judge was granted. A new
judge took charge of the case and revoked the prior judges
order closing the evidentiary phase
40
of the case. On December 17, 2010, the judge issued an
order closing the evidentiary phase of the case and notifying
the parties that he had requested the case file so that he could
prepare a judgment.
Chevron and Texpet filed an arbitration claim in September 2009
against the Republic of Ecuador before the Permanent Court of
Arbitration in The Hague under the Rules of the United Nations
Commission on International Trade Law. The claim alleges
violations of the Republic of Ecuadors obligations under
the United States-Ecuador Bilateral Investment Treaty (BIT) and
breaches of the settlement and release agreements between the
Republic of Ecuador and Texpet (described above), which are
investment agreements protected by the BIT. Through the
arbitration, Chevron and Texpet are seeking relief against the
Republic of Ecuador, including a declaration that any judgment
against Chevron in the Lago Agrio litigation constitutes a
violation of Ecuadors obligations under the BIT. On
February 9, 2011, the Permanent Court of Arbitration issued
an Order for Interim Measures requiring the Republic of Ecuador
to take all measures at its disposal to suspend or cause to be
suspended the enforcement or recognition within and without
Ecuador of any judgment against Chevron in the Lago Agrio case
pending further order of the Tribunal. Chevron expects to
continue seeking permanent injunctive relief and monetary relief
before the Tribunal.
Through a series of recent U.S. court proceedings initiated
by Chevron to obtain discovery relating to the Lago Agrio
litigation and the BIT arbitration, Chevron has obtained
evidence that it believes shows a pattern of fraud, collusion,
corruption, and other misconduct on the part of several lawyers,
consultants and others acting for the Lago Agrio plaintiffs. In
February 2011, Chevron filed a civil lawsuit in the Federal
District Court for the Southern District of New York against the
Lago Agrio plaintiffs and several of their lawyers, consultants
and supporters, alleging violations of the Racketeer Influenced
and Corrupt Organizations Act and other state laws. Through the
civil lawsuit, Chevron is seeking relief that includes an award
of damages and a declaration that any judgment against Chevron
in the Lago Agrio litigation is the result of fraud and other
unlawful conduct and is therefore unenforceable. On
March 7, 2011, the Federal District Court issued a
preliminary injunction prohibiting the Lago Agrio plaintiffs and
persons acting in concert with them from taking any action in
furtherance of recognition or enforcement of any judgment
against Chevron in the Lago Agrio case pending resolution of
Chevrons civil lawsuit by the Federal District Court. The
defendents appealed the preliminary injunction to the
U.S. Court of Appeals for the Second Circuit. The Federal
District Court has set a trial date of November 14, 2011
for Chevrons claim for declaratory relief.
On February 14, 2011, the Provincial Court in Lago Agrio
rendered an adverse judgment in the case. The Provincial Court
rejected Chevrons defenses to the extent the Court
addressed them in its opinion. The judgment assessed
approximately $8.6 billion in damages and approximately
$0.9 billion as an award for the plaintiffs
representatives. It also assessed an additional amount of
approximately $8.6 billion in punitive damages unless the
company issued a public apology within fifteen days of the
judgment, which Chevron did not do. On February 17, 2011,
the plaintiffs appealed the judgment, seeking increased damages,
and on March 11, 2011, Chevron appealed the judgment,
seeking to have the judgment nullified. Chevron continues to
believe the Courts judgment is illegitimate and
unenforceable in Ecuador, the United States and other countries.
The company also believes the judgment is the product of fraud,
and contrary to the legitimate scientific evidence. Chevron
cannot predict the timing or ultimate outcome of the appeals
process in Ecuador. Chevron will continue a vigorous defense of
any imposition of liability. Because Chevron has no substantial
assets in Ecuador, Chevron would expect enforcement actions as a
result of this judgment to be brought in other jurisdictions.
Chevron expects to contest any such actions.
The ultimate outcome of the foregoing matters, including any
financial effect on Chevron, remains uncertain. Management does
not believe an estimate of a reasonably possible loss (or a
range of loss) can be made in this case. Due to the defects
associated with the judgment, the 2008 engineers report
and the September 2010 plaintiffs submission, management
does not believe these documents have any utility in calculating
a reasonably possible loss (or a range of loss). Moreover, the
highly uncertain legal environment surrounding the case provides
no basis for management to estimate a reasonably possible loss
(or a range of loss).
Government Proceedings On January 7, 2011, the South
Coast Air Quality Management District (SCAQMD) issued a Notice
of Violation (NOV) to the companys Huntington Beach,
California, terminal seeking a civil penalty for alleged
violations involving the repair of two holes in the roof of a
tank at the terminal. Based on a July 8, 2011
41
settlement communication with the SCAQMD, it appears that the
resolution of this NOV will result in the payment of a civil
penalty exceeding $100,000.
On August 2, 2011, the Bay Area Air Quality Management
District (BAAQMD) and the company executed a settlement
regarding the companys Richmond Refinery for alleged
violations of BAAQMDs regulations governing flaring. The
settlement agreement contains a $170,000 civil penalty
assessment.
On June 14, 2011, after a contested hearing, the United
States Department of Transportation Pipeline and Hazardous
Material Safety Administration assessed Chevron Pipe Line
Company a $100,000 civil penalty as the result of a violation
arising out of the rupture of two pipelines by third parties.
Both events occurred in 2008, with the first involving a
pipeline in Hobbs, New Mexico, and the second involving a
pipeline in Snyder, Texas. The penalty has been paid.
On July 15, 2011, the Maine Department of Environmental
Protection and the company executed a settlement alleging
violations associated with the discharge of petroleum to waters
of the state from two former marketing terminals in Hampden,
Maine. The settlement agreement contains a $380,000 civil
penalty assessment and a cash payment of $520,000 for a
supplemental environmental project.
Chevron is a global energy 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
June 30, 2011, does not differ materially from that set
forth in Part I, Item 1A, of Chevrons 2010
Annual Report on
Form 10-K.
|
|
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)(2)
|
|
per Share
|
|
Announced Program
|
|
the Program(2)
|
|
April 1-30, 2011
|
|
|
2,344,910
|
|
|
|
107.33
|
|
|
|
2,329,493
|
|
|
|
|
|
May 1-31, 2011
|
|
|
3,637,738
|
|
|
|
103.33
|
|
|
|
3,629,337
|
|
|
|
|
|
June 1-30, 2011
|
|
|
3,783,218
|
|
|
|
100.28
|
|
|
|
3,739,413
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
9,765,866
|
|
|
|
103.11
|
|
|
|
9,698,243
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
|
Includes common shares repurchased during the three-month period
ended June 30, 2011, from company employees for required
personal income tax withholdings on the exercise of the stock
options issued to management under long-term incentive plans and
former Texaco Inc. and Unocal stock option 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
June 30, 2011. |
|
(2) |
|
In July 2010, the Board of Directors approved an ongoing share
repurchase program with no set term or monetary limits, under
which common shares would be acquired by the company through
open market purchases (some pursuant to a
Rule 10b5-1
plan) at prevailing prices, as permitted by securities laws and
other legal requirements and subject to market conditions and
other factors. As of June 30, 2011, 26,106,655 shares
had been acquired under this program for $2.5 billion. |
42
|
|
|
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 company 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
|
(99.1)
|
|
Mine Safety Disclosure
|
(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.
43
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)
Matthew J. Foehr, Vice President and Comptroller
(Principal Accounting Officer and
Duly Authorized Officer)
Date: August 4, 2011
44
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 company 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
|
(99.1)*
|
|
Mine Safety Disclosure
|
(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.
45