CHEVRON CORP
10-Qs and 10-Ks
PROXIES
Table of Contents
UNITED STATES SECURITIES AND
EXCHANGE COMMISSION
Washington, D.C. 20549
Washington, D.C. 20549
Form 10-Q
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þ
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QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934 |
|
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For the quarterly period ended
September 30,
2010
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or
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|
o
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TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934 |
|
Commission file number
001-00368
Chevron Corporation
(Exact name of registrant as
specified in its charter)
|
Delaware
|
94-0890210 | |
|
(State or other jurisdiction
of
incorporation or organization) |
(I.R.S. Employer
Identification No.) |
|
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6001 Bollinger Canyon Road,
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94583-2324 | |
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San Ramon, California
|
(Zip Code) | |
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(Address of principal executive offices)
|
Registrant’s 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):
| Large accelerated filer þ | Accelerated filer o | Non-accelerated filer o | Smaller reporting company o |
(Do not check if a smaller
reporting company)
Indicate by check mark whether the registrant is a shell company
(as defined in
Rule 12b-2
of the Exchange
Act). Yes
o
No
þ
Indicate the number of shares outstanding of each of the
issuer’s classes of common stock, as of the latest
practicable date:
| Class | Outstanding as of September 30, 2010 | |
|
Common stock, $.75 par value
|
2,012,428,494 |
INDEX
1
Table of Contents
CAUTIONARY
STATEMENT RELEVANT TO FORWARD-LOOKING INFORMATION
FOR THE PURPOSE OF “SAFE HARBOR” PROVISIONS OF THE
PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995
FOR THE PURPOSE OF “SAFE HARBOR” PROVISIONS OF THE
PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995
This quarterly report on
Form 10-Q
of Chevron Corporation contains forward-looking statements
relating to Chevron’s operations that are based on
management’s current expectations, estimates and
projections about the petroleum, chemicals and other
energy-related industries. Words such as
“anticipates,” “expects,”
“intends,” “plans,” “targets,”
“projects,” “believes,” “seeks,”
“schedules,” “estimates,”
“budgets” and similar expressions are intended to
identify such forward-looking statements. These statements are
not guarantees of future performance and are subject to certain
risks, uncertainties and other factors, some of which are beyond
the company’s control and are difficult to predict.
Therefore, actual outcomes and results may differ materially
from what is expressed or forecasted in such forward-looking
statements. The reader should not place undue reliance on these
forward-looking statements, which speak only as of the date of
this report. Unless legally required, Chevron undertakes no
obligation to update publicly any forward-looking statements,
whether as a result of new information, future events or
otherwise.
Among the important factors that could cause actual results to
differ materially from those in the forward-looking statements
are: 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 company’s joint-venture
partners to fund their share of operations and development
activities; the potential failure to achieve expected net
production from existing and future crude oil and natural gas
development projects; potential delays in the development,
construction or
start-up
of
planned projects; the potential disruption or interruption of
the company’s net production or manufacturing facilities or
delivery/transportation networks due to war, accidents,
political events, civil unrest, severe weather or crude oil
production quotas that might be imposed by the Organization of
Petroleum Exporting Countries; 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
company’s 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 30 through
32 of the company’s 2009 Annual Report on
Form 10-K.
In addition, such statements could be affected by general
domestic and international economic and political conditions.
Unpredictable or unknown factors not discussed in this report
could also have material adverse effects on forward-looking
statements.
2
Table of Contents
PART I.
FINANCIAL
INFORMATION
| Item 1. | Consolidated Financial Statements |
CHEVRON
CORPORATION AND SUBSIDIARIES
(Unaudited)
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars, except per-share amounts) | ||||||||||||||||
|
Revenues and Other Income
|
||||||||||||||||
|
Sales and other operating revenues*
|
$ | 48,554 | $ | 45,180 | $ | 146,346 | $ | 119,814 | ||||||||
|
Income from equity affiliates
|
1,242 | 1,072 | 4,127 | 2,418 | ||||||||||||
|
Other (loss) income
|
(78 | ) | 373 | 428 | 728 | |||||||||||
|
Total Revenues and Other Income
|
49,718 | 46,625 | 150,901 | 122,960 | ||||||||||||
|
Costs and Other Deductions
|
||||||||||||||||
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Purchased crude oil and products
|
28,610 | 26,969 | 86,358 | 71,047 | ||||||||||||
|
Operating expenses
|
4,665 | 4,403 | 13,845 | 12,958 | ||||||||||||
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Selling, general and administrative expenses
|
1,181 | 1,177 | 3,359 | 3,197 | ||||||||||||
|
Exploration expenses
|
420 | 242 | 812 | 1,061 | ||||||||||||
|
Depreciation, depletion and amortization
|
3,401 | 2,988 | 9,624 | 8,954 | ||||||||||||
|
Taxes other than on income*
|
4,559 | 4,644 | 13,568 | 13,008 | ||||||||||||
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Interest and debt expense
|
9 | 14 | 46 | 28 | ||||||||||||
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Total Costs and Other Deductions
|
42,845 | 40,437 | 127,612 | 110,253 | ||||||||||||
|
Income Before Income Tax Expense
|
6,873 | 6,188 | 23,289 | 12,707 | ||||||||||||
|
Income Tax Expense
|
3,081 | 2,342 | 9,473 | 5,246 | ||||||||||||
|
Net Income
|
3,792 | 3,846 | 13,816 | 7,461 | ||||||||||||
|
Less: Net income attributable to noncontrolling interests
|
24 | 15 | 87 | 48 | ||||||||||||
|
Net Income Attributable to Chevron Corporation
|
$ | 3,768 | $ | 3,831 | $ | 13,729 | $ | 7,413 | ||||||||
|
Per Share of Common Stock:
|
||||||||||||||||
|
Net Income Attributable to Chevron Corporation
|
||||||||||||||||
|
— Basic
|
$ | 1.89 | $ | 1.92 | $ | 6.88 | $ | 3.72 | ||||||||
|
— Diluted
|
$ | 1.87 | $ | 1.92 | $ | 6.84 | $ | 3.71 | ||||||||
|
Dividends
|
$ | 0.72 | $ | 0.68 | $ | 2.12 | $ | 1.98 | ||||||||
|
Weighted Average Number of Shares Outstanding (000s)
|
||||||||||||||||
|
— Basic
|
1,997,721 | 1,992,452 | 1,996,376 | 1,991,733 | ||||||||||||
|
— Diluted
|
2,006,785 | 2,000,586 | 2,005,677 | 1,999,925 | ||||||||||||
|
|
||||||||||||||||
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* Includes excise, value-added and similar taxes:
|
$ | 2,182 | $ | 2,079 | $ | 6,455 | $ | 6,023 | ||||||||
See accompanying notes to consolidated financial statements.
3
Table of Contents
CHEVRON
CORPORATION AND SUBSIDIARIES
(Unaudited)
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Net Income
|
$3,792 | $3,846 | $13,816 | $7,461 | ||||||||||||
|
Currency translation adjustment
|
46 | 31 | 33 | 44 | ||||||||||||
|
Unrealized holding loss on securities:
|
||||||||||||||||
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Net gain (loss) arising during period
|
3 | 8 | (1 | ) | 3 | |||||||||||
|
Derivatives:
|
||||||||||||||||
|
Net derivatives gain (loss) on hedge transactions
|
43 | 7 | 67 | (65 | ) | |||||||||||
|
Reclassification to net income of net realized
loss (gain) |
4 | (9 | ) | 7 | (25 | ) | ||||||||||
|
Income taxes on derivatives transactions
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(16 | ) | 1 | (26 | ) | 31 | ||||||||||
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Total
|
31 | (1 | ) | 48 | (59 | ) | ||||||||||
|
Defined benefit plans:
|
||||||||||||||||
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Actuarial loss:
|
||||||||||||||||
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Amortization to net income of net actuarial loss
|
165 | 136 | 497 | 451 | ||||||||||||
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Prior service cost:
|
||||||||||||||||
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Amortization to net income of net prior service credits
|
(15 | ) | (15 | ) | (45 | ) | (49 | ) | ||||||||
|
Defined benefit plans sponsored by equity affiliates
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8 | 5 | 22 | 10 | ||||||||||||
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Income taxes on defined benefit plans
|
(52 | ) | (45 | ) | (173 | ) | (152 | ) | ||||||||
|
Total
|
106 | 81 | 301 | 260 | ||||||||||||
|
Other Comprehensive Gain, Net of Tax
|
186 | 119 | 381 | 248 | ||||||||||||
|
Comprehensive Income
|
3,978 | 3,965 | 14,197 | 7,709 | ||||||||||||
|
Comprehensive income attributable to noncontrolling interests
|
(24 | ) | (15 | ) | (87 | ) | (48 | ) | ||||||||
|
Comprehensive Income Attributable to Chevron Corporation
|
$3,954 | $3,950 | $14,110 | $7,661 | ||||||||||||
See accompanying notes to consolidated financial statements.
4
Table of Contents
CHEVRON
CORPORATION AND SUBSIDIARIES
(Unaudited)
|
At September 30
|
At December 31
|
|||||||
| 2010 | 2009 | |||||||
|
(Millions of dollars, except
|
||||||||
| per-share amounts) | ||||||||
|
ASSETS
|
||||||||
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Cash and cash equivalents
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$ 10,995 | $ 8,716 | ||||||
|
Time deposits
|
3,473 | — | ||||||
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Marketable securities
|
66 | 106 | ||||||
|
Accounts and notes receivable, net
|
17,994 | 17,703 | ||||||
|
Inventories:
|
||||||||
|
Crude oil and petroleum products
|
4,147 | 3,680 | ||||||
|
Chemicals
|
436 | 383 | ||||||
|
Materials, supplies and other
|
1,554 | 1,466 | ||||||
|
Total inventories
|
6,137 | 5,529 | ||||||
|
Prepaid expenses and other current assets
|
5,818 | 5,162 | ||||||
|
Total Current Assets
|
44,483 | 37,216 | ||||||
|
Long-term receivables, net
|
2,147 | 2,282 | ||||||
|
Investments and advances
|
21,764 | 21,158 | ||||||
|
Properties, plant and equipment, at cost
|
202,108 | 188,288 | ||||||
|
Less: Accumulated depreciation, depletion and amortization
|
100,376 | 91,820 | ||||||
|
Properties, plant and equipment, net
|
101,732 | 96,468 | ||||||
|
Deferred charges and other assets
|
2,455 | 2,879 | ||||||
|
Goodwill
|
4,618 | 4,618 | ||||||
|
Total Assets
|
$177,199 | $164,621 | ||||||
| LIABILITIES AND EQUITY | ||||||||
|
Short-term debt
|
$ 170 | $ 384 | ||||||
|
Accounts payable
|
17,237 | 16,437 | ||||||
|
Accrued liabilities
|
5,405 | 5,375 | ||||||
|
Federal and other taxes on income
|
2,588 | 2,624 | ||||||
|
Other taxes payable
|
1,450 | 1,391 | ||||||
|
Total Current Liabilities
|
26,850 | 26,211 | ||||||
|
Long-term debt
|
10,143 | 9,829 | ||||||
|
Capital lease obligations
|
306 | 301 | ||||||
|
Deferred credits and other noncurrent obligations
|
18,409 | 17,390 | ||||||
|
Noncurrent deferred income taxes
|
12,204 | 11,521 | ||||||
|
Reserves for employee benefit plans
|
6,322 | 6,808 | ||||||
|
Total Liabilities
|
74,234 | 72,060 | ||||||
|
Preferred stock (authorized 100,000,000 shares,
$1.00 par value, none issued)
|
— | — | ||||||
|
Common stock (authorized 6,000,000,000 shares,
$.75 par value, 2,442,676,580 shares issued at
September 30, 2010, and December 31, 2009)
|
1,832 | 1,832 | ||||||
|
Capital in excess of par value
|
14,767 | 14,631 | ||||||
|
Retained earnings
|
115,784 | 106,289 | ||||||
|
Accumulated other comprehensive loss
|
(3,940 | ) | (4,321 | ) | ||||
|
Deferred compensation and benefit plan trust
|
(312 | ) | (349 | ) | ||||
|
Treasury stock, at cost (430,248,086 and 434,954,774 shares
at September 30, 2010, and December 31, 2009,
respectively)
|
(25,888 | ) | (26,168 | ) | ||||
|
Total Chevron Corporation Stockholders’ Equity
|
102,243 | 91,914 | ||||||
|
Noncontrolling interests
|
722 | 647 | ||||||
|
Total Equity
|
102,965 | 92,561 | ||||||
|
Total Liabilities and Equity
|
$177,199 | $164,621 | ||||||
See accompanying notes to consolidated financial statements.
5
Table of Contents
CHEVRON
CORPORATION AND SUBSIDIARIES
(Unaudited)
|
Nine Months Ended
|
||||||||
| September 30 | ||||||||
| 2010 | 2009 | |||||||
| (Millions of dollars) | ||||||||
|
Operating Activities
|
||||||||
|
Net Income
|
$ 13,816 | $ 7,461 | ||||||
|
Adjustments
|
||||||||
|
Depreciation, depletion and amortization
|
9,624 | 8,954 | ||||||
|
Dry hole expense
|
381 | 481 | ||||||
|
Distributions less than income from equity affiliates
|
(153 | ) | (510 | ) | ||||
|
Net before-tax gains on asset retirements and sales
|
(359 | ) | (1,083 | ) | ||||
|
Net foreign currency effects
|
203 | 481 | ||||||
|
Deferred income tax provision
|
(60 | ) | 335 | |||||
|
Net increase in operating working capital
|
(132 | ) | (2,993 | ) | ||||
|
Increase in long-term receivables
|
(47 | ) | (288 | ) | ||||
|
Decrease in other deferred charges
|
48 | 131 | ||||||
|
Cash contributions to employee pension plans
|
(895 | ) | (860 | ) | ||||
|
Other
|
676 | 244 | ||||||
|
Net Cash Provided by Operating Activities
|
23,102 | 12,353 | ||||||
|
Investing Activities
|
||||||||
|
Capital expenditures
|
(14,108 | ) | (14,488 | ) | ||||
|
Proceeds and deposits related to asset sales
|
543 | 2,132 | ||||||
|
Net purchases of time deposits
|
(3,473 | ) | — | |||||
|
Net sales of marketable securities
|
41 | 113 | ||||||
|
Repayment of loans by equity affiliates
|
169 | 167 | ||||||
|
Net (purchases) sales of other short-term investments
|
(63 | ) | 153 | |||||
|
Net Cash Used for Investing Activities
|
(16,891 | ) | (11,923 | ) | ||||
|
Financing Activities
|
||||||||
|
Net payments of short-term obligations
|
(169 | ) | (3,258 | ) | ||||
|
Proceeds from issuance of long-term debt
|
350 | 5,339 | ||||||
|
Repayments of long-term debt and other financing obligations
|
(107 | ) | (461 | ) | ||||
|
Cash dividends
|
(4,233 | ) | (3,945 | ) | ||||
|
Distributions to noncontrolling interests
|
(56 | ) | (37 | ) | ||||
|
Net sales of treasury shares
|
245 | 86 | ||||||
|
Net Cash Used for Financing Activities
|
(3,970 | ) | (2,276 | ) | ||||
|
Effect of Exchange Rate Changes on Cash and Cash
Equivalents
|
38 | 67 | ||||||
|
Net Change in Cash and Cash Equivalents
|
2,279 | (1,779 | ) | |||||
|
Cash and Cash Equivalents at January 1
|
8,716 | 9,347 | ||||||
|
Cash and Cash Equivalents at September 30
|
$ 10,995 | $ 7,568 | ||||||
See accompanying notes to consolidated financial statements.
6
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL STATEMENTS
| Note 1. | Interim Financial Statements |
The accompanying consolidated financial statements of Chevron
Corporation and its subsidiaries (the company) have not been
audited by an independent registered public accounting firm. In
the opinion of the company’s management, the interim data
include all adjustments necessary for a fair statement of the
results for the interim periods. These adjustments were of a
normal recurring nature. The results for the three- and
nine-month periods ended September 30, 2010, are not
necessarily indicative of future financial results. The term
“earnings” is defined as net income attributable to
Chevron Corporation.
Effective January 1, 2010, Chevron’s segment reporting
reflects the reclassification of certain businesses. Prior
period information was revised to conform to the 2010
presentation. Refer to “Note 5. Operating Segments and
Geographic Data,” beginning on page 9, for a
discussion of the changes.
Certain notes and other information have been condensed or
omitted from the interim financial statements presented in this
Quarterly Report on
Form 10-Q.
Therefore, these financial statements should be read in
conjunction with the company’s 2009 Annual Report on
Form 10-K.
Earnings for the first nine months of 2010 included after-tax
charges of $175 million associated with employee reductions
in the downstream businesses and corporate staffs. Refer to
“Note 16. Restructuring and Reorganization
Costs,” beginning on page 22, for further discussion.
Earnings for the third quarter 2009 included $400 million
of after-tax gains from asset sales and tax items related to an
upstream project in Australia. Earnings for the first nine
months of 2009 also included $540 million of after-tax
gains reported on sales of marketing businesses outside the
United States.
| Note 2. | Time Deposits |
In the first quarter 2010, the company began investing in bank
time deposits with maturities greater than 90 days. The
company believes that the investment in longer-term bank time
deposits is consistent with its cash management strategy to
preserve principal, maintain high levels of liquidity and earn a
competitive return.
| Note 3. | Noncontrolling Interests |
Ownership interests in the company’s subsidiaries held by
parties other than the parent are presented separately from the
parent’s equity on the Consolidated Balance Sheet. The
amounts of consolidated net income attributable to the parent
and the noncontrolling interests are both presented on the face
of the Consolidated Statement of Income. Activity for the equity
attributable to noncontrolling interests for the first nine
months of 2010 and 2009 is presented in the following table:
| 2010 | 2009 | |||||||||||||||||||||||
|
Chevron Corporation
|
Noncontrolling
|
Total
|
Chevron Corporation
|
Noncontrolling
|
Total
|
|||||||||||||||||||
| Stockholders’ Equity | Interest | Equity | Stockholders’ Equity | Interest | Equity | |||||||||||||||||||
| (Millions of dollars) | ||||||||||||||||||||||||
|
Balance at January 1
|
$ 91,914 | $647 | $ 92,561 | $86,648 | $469 | $87,117 | ||||||||||||||||||
|
Net income
|
13,729 | 87 | 13,816 | 7,413 | 48 | 7,461 | ||||||||||||||||||
|
Dividends
|
(4,233 | ) | — | (4,233 | ) | (3,945 | ) | — | (3,945 | ) | ||||||||||||||
|
Distributions to noncontrolling interests
|
— | (56 | ) | (56 | ) | — | (37 | ) | (37 | ) | ||||||||||||||
|
Treasury shares, net
|
280 | — | 280 | 121 | — | 121 | ||||||||||||||||||
|
Other changes, net*
|
553 | 44 | 597 | 409 | 96 | 505 | ||||||||||||||||||
|
Balance at September 30
|
$102,243 | $722 | $102,965 | $90,646 | $576 | $91,222 | ||||||||||||||||||
| * | Includes components of comprehensive income, which are disclosed separately in the Consolidated Statement of Comprehensive Income. |
7
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
| Note 4. | Information Relating to the Consolidated Statement of Cash Flows |
The “Net increase in operating working capital” was
composed of the following operating changes:
|
Nine Months Ended
|
||||||||
| September 30 | ||||||||
| 2010 | 2009 | |||||||
| (Millions of dollars) | ||||||||
|
Increase in accounts and notes receivable
|
$ (13 | ) | $ (877 | ) | ||||
|
(Increase) decrease in inventories
|
(608 | ) | 356 | |||||
|
Increase in prepaid expenses and other current assets
|
(646 | ) | (216 | ) | ||||
|
Increase (decrease) in accounts payable and accrued liabilities
|
718 | (1,597 | ) | |||||
|
Increase (decrease) in income and other taxes payable
|
417 | (659 | ) | |||||
|
Net increase in operating working capital
|
$(132 | ) | $(2,993 | ) | ||||
The “Net increase in operating working capital”
includes reductions of $37 million and $11 million for
excess income tax benefits associated with stock options
exercised during the nine months ended September 30, 2010,
and 2009, respectively. These amounts are offset by an equal
amount in “Net sales of treasury shares.”
“Net Cash Provided by Operating Activities” included
the following cash payments for interest on debt and for income
taxes:
|
Nine Months Ended
|
||||||||
| September 30 | ||||||||
| 2010 | 2009 | |||||||
| (Millions of dollars) | ||||||||
|
Interest on debt (net of capitalized interest)
|
$ | 92 | $ | 11 | ||||
|
Income taxes
|
9,014 | 4,825 | ||||||
The “Net purchases of time deposits” consisted of the
following gross amounts:
|
Nine Months Ended
|
||||||||
| September 30 | ||||||||
| 2010 | 2009 | |||||||
| (Millions of dollars) | ||||||||
|
Time deposits purchased
|
$(4,868 | ) | $— | |||||
|
Time deposits matured
|
1,395 | — | ||||||
|
Net purchases of time deposits
|
$(3,473 | ) | $— | |||||
The “Net sales of marketable securities” consisted of
the following gross amounts:
|
Nine Months Ended
|
||||||||
| September 30 | ||||||||
| 2010 | 2009 | |||||||
| (Millions of dollars) | ||||||||
|
Marketable securities purchased
|
$— | $ (24 | ) | |||||
|
Marketable securities sold
|
41 | 137 | ||||||
|
Net sales of marketable securities
|
$41 | $113 | ||||||
The “Net sales of treasury shares” represents the cost
of common shares acquired less the cost of shares issued for
share-based compensation plans. Net sales totaled
$245 million and $86 million in the first nine months
of 2010 and 2009, respectively. No purchases were made under the
company’s stock repurchase program in the 2010 and 2009
periods.
8
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
The major components of “Capital expenditures” and the
reconciliation of this amount to the capital and exploratory
expenditures, including equity affiliates, are as follows:
|
Nine Months Ended
|
||||||||
| September 30 | ||||||||
| 2010 | 2009 | |||||||
| (Millions of dollars) | ||||||||
|
Additions to properties, plant and equipment
|
$13,242 | $11,542 | ||||||
|
Additions to investments
|
617 | 793 | ||||||
|
Current year dry hole expenditures
|
348 | 399 | ||||||
|
Payments for other liabilities and assets, net
|
(99 | ) | 1,754 | |||||
|
Capital expenditures
|
14,108 | 14,488 | ||||||
|
Expensed exploration expenditures
|
431 | 580 | ||||||
|
Assets acquired through capital lease obligations
|
56 | 20 | ||||||
|
Capital and exploratory expenditures, excluding equity affiliates
|
14,595 | 15,088 | ||||||
|
Company’s share of expenditures by equity affiliates
|
942 | 923 | ||||||
|
Capital and exploratory expenditures, including equity affiliates
|
$15,537 | $16,011 | ||||||
“Payments for other liabilities and assets, net” in
the 2009 period include $2 billion for a cash payment
related to an accrual recorded in 2008 for the extension of an
upstream operating agreement outside the United States.
| Note 5. | Operating Segments and Geographic Data |
Although each subsidiary of Chevron is responsible for its own
affairs, Chevron Corporation manages its investments in these
subsidiaries and their affiliates. The investments are grouped
into two business segments, Upstream and Downstream,
representing the company’s “reportable segments”
and “operating segments” as defined in accounting
standards for segment reporting (ASC 280). Upstream operations
consist primarily of exploring for, developing and producing
crude oil and natural gas; processing, liquefaction,
transportation and regasification associated with liquefied
natural gas (LNG); transporting crude oil by major international
oil export pipelines; 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 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,
alternative fuels and technology.
The segments are separately managed for investment purposes
under a structure that includes “segment managers” who
report to the company’s “chief operating decision
maker” (CODM) (terms as defined in the accounting
standards). The CODM is the company’s Executive Committee
(EXCOM), a committee of senior officers that includes the Chief
Executive Officer, and EXCOM reports to the Board of Directors
of Chevron Corporation.
The operating segments represent components of the company as
described in the accounting standards that engage in activities
(a) from which revenues are earned and expenses are
incurred; (b) whose operating results are regularly
reviewed by the CODM, which makes decisions about resources to
be allocated to the segments and assesses their performance; and
(c) for which discrete financial information is available.
Segment managers for the reportable segments are directly
accountable to and maintain regular contact with the
company’s CODM to discuss the 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
9
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
implementation and all other matters connected with daily
operations. Company officers who are members of EXCOM also have
individual management responsibilities and participate in other
committees for purposes other than acting as the CODM.
The activities reported in Chevron’s upstream and
downstream operating segments have changed effective
January 1, 2010. Chemicals businesses are now reported as
part of the downstream segment. In addition, the company’s
significant upstream-enabling operations, primarily a
gas-to-liquids
project and major international export pipelines, have been
reclassified from the downstream segment to the upstream
segment. Prior period information in this report has been
revised to conform to the 2010 presentation.
The company’s primary country of operation is the United
States of America, its country of domicile. Other components of
the company’s operations are reported as
“International” (outside the United States).
Segment Earnings
The company evaluates the performance of
its operating segments on an after-tax basis, without
considering the effects of debt financing interest expense or
investment interest income, both of which are managed by the
company on a worldwide basis. Corporate administrative costs and
assets are not allocated to the operating segments. However,
operating segments are billed for the direct use of corporate
services. Nonbillable costs remain at the corporate level in
“All Other.” Earnings by major operating area for the
three- and nine-month periods ended September 30, 2010 and
2009 are presented in the following table:
Segment
Earnings
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Upstream
|
||||||||||||||||
|
United States
|
$ | 946 | $ | 889 | $ | 3,192 | $ | 1,196 | ||||||||
|
International
|
2,618 | 2,847 | 9,638 | 5,575 | ||||||||||||
|
Total Upstream
|
3,564 | 3,736 | 12,830 | 6,771 | ||||||||||||
|
Downstream
|
||||||||||||||||
|
United States
|
349 | 127 | 864 | 212 | ||||||||||||
|
International
|
216 | 135 | 872 | 934 | ||||||||||||
|
Total Downstream
|
565 | 262 | 1,736 | 1,146 | ||||||||||||
|
Total Segment Earnings
|
4,129 | 3,998 | 14,566 | 7,917 | ||||||||||||
|
All Other
|
||||||||||||||||
|
Interest Expense
|
(7 | ) | (11 | ) | (37 | ) | (22 | ) | ||||||||
|
Interest Income
|
16 | 10 | 49 | 36 | ||||||||||||
|
Other
|
(370 | ) | (166 | ) | (849 | ) | (518 | ) | ||||||||
|
Net Income Attributable to Chevron Corporation
|
$ | 3,768 | $ | 3,831 | $ | 13,729 | $ | 7,413 | ||||||||
10
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
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
September 30, 2010, and December 31, 2009, are as
follows:
Segment
Assets
|
At September 30
|
At December 31
|
|||||||
| 2010 | 2009 | |||||||
| (Millions of dollars) | ||||||||
|
Upstream
|
||||||||
|
United States
|
$ 25,700 | $ 25,478 | ||||||
|
International
|
86,532 | 81,209 | ||||||
|
Goodwill
|
4,617 | 4,618 | ||||||
|
Total Upstream
|
116,849 | 111,305 | ||||||
|
Downstream
|
||||||||
|
United States
|
20,365 | 20,317 | ||||||
|
International
|
20,376 | 19,618 | ||||||
|
Total Downstream
|
40,741 | 39,935 | ||||||
|
Total Segment Assets
|
157,590 | 151,240 | ||||||
|
All Other
|
||||||||
|
United States
|
9,620 | 7,125 | ||||||
|
International
|
9,989 | 6,256 | ||||||
|
Total All Other
|
19,609 | 13,381 | ||||||
|
Total Assets — United States
|
55,685 | 52,920 | ||||||
|
Total Assets — International
|
116,897 | 107,083 | ||||||
|
Goodwill
|
4,617 | 4,618 | ||||||
|
Total Assets
|
$177,199 | $164,621 | ||||||
Segment Sales and Other Operating Revenues
Segment sales
and other operating revenues, including internal transfers, for
the three- and nine-month periods ended September 30, 2010
and 2009, 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.
11
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
Sales and
Other Operating Revenues
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Upstream
|
||||||||||||||||
|
United States
|
$ 5,892 | $ 4,985 | $ 18,207 | $ 13,657 | ||||||||||||
|
International
|
9,984 | 8,335 | 29,642 | 22,297 | ||||||||||||
|
Subtotal
|
15,876 | 13,320 | 47,849 | 35,954 | ||||||||||||
|
Intersegment Elimination — United States
|
(3,299 | ) | (3,014 | ) | (10,142 | ) | (6,925 | ) | ||||||||
|
Intersegment Elimination — International
|
(5,623 | ) | (4,866 | ) | (17,141 | ) | (12,696 | ) | ||||||||
|
Total Upstream
|
6,954 | 5,440 | 20,566 | 16,333 | ||||||||||||
|
Downstream
|
||||||||||||||||
|
United States
|
18,438 | 18,025 | 55,378 | 44,699 | ||||||||||||
|
International
|
23,042 | 21,557 | 70,102 | 58,389 | ||||||||||||
|
Subtotal
|
41,480 | 39,582 | 125,480 | 103,088 | ||||||||||||
|
Intersegment Elimination — United States
|
(31 | ) | (19 | ) | (80 | ) | (76 | ) | ||||||||
|
Intersegment Elimination — International
|
(27 | ) | (25 | ) | (75 | ) | (59 | ) | ||||||||
|
Total Downstream
|
41,422 | 39,538 | 125,325 | 102,953 | ||||||||||||
|
All Other
|
||||||||||||||||
|
United States
|
413 | 473 | 1,088 | 1,180 | ||||||||||||
|
International
|
13 | 19 | 46 | 48 | ||||||||||||
|
Subtotal
|
426 | 492 | 1,134 | 1,228 | ||||||||||||
|
Intersegment Elimination — United States
|
(239 | ) | (281 | ) | (652 | ) | (679 | ) | ||||||||
|
Intersegment Elimination — International
|
(9 | ) | (9 | ) | (27 | ) | (21 | ) | ||||||||
|
Total All Other
|
178 | 202 | 455 | 528 | ||||||||||||
|
Sales and Other Operating Revenues
|
||||||||||||||||
|
United States
|
24,743 | 23,483 | 74,673 | 59,536 | ||||||||||||
|
International
|
33,039 | 29,911 | 99,790 | 80,734 | ||||||||||||
|
Subtotal
|
57,782 | 53,394 | 174,463 | 140,270 | ||||||||||||
|
Intersegment Elimination — United States
|
(3,569 | ) | (3,314 | ) | (10,874 | ) | (7,680 | ) | ||||||||
|
Intersegment Elimination — International
|
(5,659 | ) | (4,900 | ) | (17,243 | ) | (12,776 | ) | ||||||||
|
Total Sales and Other Operating Revenues
|
$48,554 | $45,180 | $146,346 | $119,814 | ||||||||||||
12
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
| Note 6. | Summarized Financial Data — Chevron U.S.A. Inc. |
Chevron U.S.A. Inc. (CUSA) is a major subsidiary of Chevron
Corporation. CUSA and its subsidiaries manage and operate most
of Chevron’s U.S. businesses. Assets include those
related to the exploration and production of crude oil, natural
gas and natural gas liquids and those associated with refining,
marketing, and supply and distribution of products derived from
petroleum, excluding most of the regulated pipeline operations
of Chevron. CUSA also holds the company’s investment in the
Chevron Phillips Chemical Company LLC joint venture, which is
accounted for using the equity method. The summarized financial
information for CUSA and its consolidated subsidiaries is as
follows:
|
Nine Months Ended
|
||||||||
| September 30 | ||||||||
| 2010 | 2009 | |||||||
| (Millions of dollars) | ||||||||
|
Sales and other operating revenues
|
$107,595 | $86,522 | ||||||
|
Costs and other deductions
|
103,433 | 85,461 | ||||||
|
Net income attributable to CUSA
|
3,130 | 852 | ||||||
|
At September 30
|
At December 31
|
|||||||
| 2010 | 2009 | |||||||
| (Millions of dollars) | ||||||||
|
Current assets
|
$25,546 | $23,286 | ||||||
|
Other assets
|
33,653 | 32,827 | ||||||
|
Current liabilities
|
14,952 | 16,098 | ||||||
|
Other liabilities
|
15,681 | 14,625 | ||||||
|
Total CUSA net equity
|
$28,566 | $25,390 | ||||||
|
Memo: Total debt
|
$ 7,327 | $ 6,999 | ||||||
| Note 7. | Summarized Financial Data — Chevron Transport Corporation |
Chevron Transport Corporation Limited (CTC), incorporated in
Bermuda, is an indirect, wholly owned subsidiary of Chevron
Corporation. CTC is the principal operator of Chevron’s
international tanker fleet and is engaged in the marine
transportation of crude oil and refined petroleum products. Most
of CTC’s shipping revenue is derived by providing
transportation services to other Chevron companies. Chevron
Corporation has fully and unconditionally guaranteed this
subsidiary’s obligations in connection with certain debt
securities issued by a third party. Summarized financial
information for CTC and its consolidated subsidiaries is as
follows:
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Sales and other operating revenues
|
$ | 200 | $ | 153 | $ | 694 | $ | 492 | ||||||||
|
Costs and other deductions
|
228 | 186 | 755 | 565 | ||||||||||||
|
Net loss attributable to CTC
|
(28 | ) | (34 | ) | (54 | ) | (73 | ) | ||||||||
|
At September 30
|
At December 31
|
|||||||
| 2010 | 2009 | |||||||
| (Millions of dollars) | ||||||||
|
Current assets
|
$265 | $377 | ||||||
|
Other assets
|
201 | 173 | ||||||
|
Current liabilities
|
96 | 115 | ||||||
|
Other liabilities
|
74 | 90 | ||||||
|
Total CTC net equity
|
$296 | $345 | ||||||
There were no restrictions on CTC’s ability to pay
dividends or make loans or advances at September 30, 2010.
13
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
| Note 8. | Income Taxes |
Taxes on income for the third quarter and first nine months of
2010 were $3.1 billion and $9.5 billion, respectively,
compared with $2.3 billion and $5.2 billion for the
corresponding periods in 2009. The associated effective tax
rates (calculated as the amount of Income Tax Expense divided by
Income Before Income Tax Expense) for the third quarters of 2010
and 2009 were 45 percent and 38 percent, respectively.
For the comparative nine-month periods, the effective tax rates
were 41 percent for both periods.
The increase in the effective tax rate in the quarterly
comparison was primarily due to the effect of one-time tax
benefits in 2009 that were significantly higher than those
generated in the comparable 2010 period. Additionally, foreign
currency translation losses were greater in the 2010 quarter,
resulting in a larger reduction in Income Before Income Tax
Expense, with no corresponding impact on Income Tax Expense.
Partially offsetting these items was the increased utilization
of tax credits resulting from higher profits in certain foreign
tax jurisdictions in the 2010 period. For the comparative
nine-month periods, greater one-time tax benefits were generated
in 2009 than in 2010. This effect was essentially offset by
increased tax credit utilization in foreign tax jurisdictions in
2010 and by foreign currency translation impacts.
Tax positions for Chevron and its subsidiaries and affiliates
are subject to income tax audits by many tax jurisdictions
throughout the world. For the company’s major tax
jurisdictions, examinations of tax returns for certain prior tax
years had not been completed as of September 30, 2010. For
these jurisdictions, the latest years for which income tax
examinations had been finalized were as follows: United
States — 2005, Nigeria — 1994,
Angola — 2001 and Saudi Arabia — 2003.
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 company’s 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, we are unable
to estimate the range of possible adjustments to the balance of
unrecognized tax benefits.
| Note 9. | Employee Benefits |
Chevron has defined benefit pension plans for many employees.
The company typically prefunds defined benefit plans as required
by local regulations or in certain situations where prefunding
provides economic advantages. In the United States, all
qualified plans are subject to the Employee Retirement Income
Security Act (ERISA) minimum funding standard. The company does
not typically fund U.S. nonqualified pension plans
that are not subject to funding requirements under laws and
regulations because contributions to these pension plans may be
less economic and investment returns may be less attractive than
the company’s other investment alternatives.
The company also sponsors other postretirement (OPEB) plans that
provide medical and dental benefits, as well as life insurance
for some active and qualifying retired employees. The plans are
unfunded, and the company and the retirees share the costs.
Medical coverage for Medicare-eligible retirees in the
company’s main U.S. medical plan is secondary to
Medicare (including Part D) and the increase to the
company contribution for retiree medical coverage is limited to
no more than 4 percent each year. Certain life insurance
benefits are paid by the company.
14
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
The components of net periodic benefit costs for 2010 and 2009
are as follows:
|
Three Months
|
Nine Months
|
|||||||||||||||
|
Ended
|
Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Pension Benefits
|
||||||||||||||||
|
United States
|
||||||||||||||||
|
Service cost
|
$ 85 | $ 66 | $ 253 | $ 199 | ||||||||||||
|
Interest cost
|
121 | 121 | 364 | 361 | ||||||||||||
|
Expected return on plan assets
|
(135 | ) | (99 | ) | (404 | ) | (296 | ) | ||||||||
|
Amortization of prior-service credits
|
(1 | ) | (1 | ) | (5 | ) | (5 | ) | ||||||||
|
Amortization of actuarial losses
|
79 | 74 | 238 | 223 | ||||||||||||
|
Settlement losses
|
55 | 25 | 165 | 126 | ||||||||||||
|
Total United States
|
204 | 186 | 611 | 608 | ||||||||||||
|
International
|
||||||||||||||||
|
Service cost
|
38 | 31 | 114 | 90 | ||||||||||||
|
Interest cost
|
78 | 76 | 230 | 215 | ||||||||||||
|
Expected return on plan assets
|
(60 | ) | (52 | ) | (180 | ) | (148 | ) | ||||||||
|
Amortization of prior-service costs
|
5 | 6 | 16 | 17 | ||||||||||||
|
Amortization of actuarial losses
|
24 | 30 | 74 | 81 | ||||||||||||
|
Total International
|
85 | 91 | 254 | 255 | ||||||||||||
|
Net Periodic Pension Benefit Costs
|
$ 289 | $277 | $ 865 | $ 863 | ||||||||||||
|
Other Benefits*
|
||||||||||||||||
|
Service cost
|
$ 10 | $ 9 | $ 29 | $ 25 | ||||||||||||
|
Interest cost
|
45 | 45 | 131 | 134 | ||||||||||||
|
Amortization of prior-service credits
|
(19 | ) | (20 | ) | (56 | ) | (61 | ) | ||||||||
|
Amortization of actuarial losses
|
7 | 6 | 20 | 20 | ||||||||||||
|
Curtailment gains
|
— | — | — | (5 | ) | |||||||||||
|
Net Periodic Other Benefit Costs
|
$ 43 | $ 40 | $ 124 | $ 113 | ||||||||||||
| * | Includes costs for U.S. and international OPEB plans. Obligations for plans outside the U.S. are not significant relative to the company’s total OPEB obligation. |
At the end of 2009, the company estimated it would contribute
$900 million to employee pension plans during 2010
(composed of $600 million for the U.S. plans and
$300 million for the international plans). Through
September 30, 2010, a total of $895 million was
contributed (including $790 million to the
U.S. plans). Total contributions for the full year are
currently estimated to be $1.5 billion ($1.2 billion
for the U.S. plans and $300 million for the
international plans). Actual contribution amounts are dependent
upon investment returns, changes in pension obligations,
regulatory environments and other economic factors. Additional
funding may ultimately be required if investment returns are
insufficient to offset increases in plan obligations.
During the first nine months of 2010, the company contributed
$138 million to its OPEB plans. The company anticipates
contributing about $70 million during the remainder of 2010.
15
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
| Note 10. | Accounting for Suspended Exploratory Wells |
Accounting standards for the costs of exploratory wells (ASC
932) provide that exploratory well costs continue to be
capitalized after the completion of drilling when (a) the
well has found a sufficient quantity of reserves to justify its
completion as a producing well and (b) the entity is making
sufficient progress assessing the reserves and the economic and
operating viability of the project. If either condition is not
met or if an entity obtains information that raises substantial
doubt about the economic or operational viability of the
project, the exploratory well would be assumed to be impaired,
and its costs, net of any salvage value, would be charged to
expense. (Note that an entity is not required to complete the
exploratory or exploratory-type stratigraphic well as a
producing well.) The company’s capitalized cost of
suspended wells at September 30, 2010, was
$2.6 billion, an increase of $191 million from
year-end 2009, primarily due to drilling activities in
Australia. For the category of exploratory well costs at
year-end 2009 that were suspended more than one year, a total of
$15 million was expensed in the first nine months of 2010.
| Note 11. | 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 19 pending lawsuits and
claims, the majority of which involve numerous other petroleum
marketers and refiners. Resolution of these lawsuits and claims
may ultimately require the company to correct or ameliorate the
alleged effects on the environment of prior release of MTBE by
the company or other parties. Additional lawsuits and claims
related to the use of MTBE, including personal-injury claims,
may be filed in the future. The company’s ultimate exposure
related to pending lawsuits and claims is not determinable, but
could be material to net income in any one period. The company
no longer uses MTBE in the manufacture of gasoline in the United
States.
Ecuador
Chevron is a defendant in a civil lawsuit before
the Superior Court of Nueva Loja in Lago Agrio, Ecuador, brought
in May 2003 by plaintiffs who claim to be representatives of
certain residents of an area where an oil production consortium
formerly had operations. The lawsuit alleges damage to the
environment from the oil exploration and production operations
and seeks unspecified damages to fund environmental remediation
and restoration of the alleged environmental harm, plus a health
monitoring program. Until 1992, Texaco Petroleum Company
(Texpet), a subsidiary of Texaco Inc., was a minority member of
this consortium with Petroecuador, the Ecuadorian state-owned
oil company, as the majority partner; since 1990, the operations
have been conducted solely by Petroecuador. At the conclusion of
the consortium and following an independent third-party
environmental audit of the concession area, Texpet entered into
a formal agreement with the Republic of Ecuador and Petroecuador
for Texpet to remediate specific sites assigned by the
government in proportion to Texpet’s ownership share of the
consortium. Pursuant to that agreement, Texpet conducted a
three-year remediation program at a cost of $40 million.
After certifying that the sites were properly remediated, the
government granted Texpet and all related corporate entities a
full release from any and all environmental liability arising
from the consortium operations.
Based on the history described above, Chevron believes that this
lawsuit lacks legal or factual merit. As to matters of law, the
company believes first, that the court lacks jurisdiction over
Chevron; second, that the law under which plaintiffs bring the
action, enacted in 1999, cannot be applied retroactively; third,
that the claims are barred by the statute of limitations in
Ecuador; and, fourth, that the lawsuit is also barred by the
releases from liability previously given to Texpet by the
Republic of Ecuador and Petroecuador and by the pertinent
provincial and municipal governments. With regard to the facts,
the company believes that the evidence confirms that
Texpet’s remediation was properly conducted and that the
remaining environmental damage reflects Petroecuador’s
failure to timely fulfill its legal obligations and
Petroecuador’s further conduct since assuming full control
over the operations.
In 2008, a mining engineer appointed by the court to identify
and determine the cause of environmental damage, and to specify
steps needed to remediate it, issued a report recommending that
the court assess $18.9 billion, which would, according to
the engineer, provide financial compensation for purported
damages, including wrongful death claims, and pay for, among
other items, environmental remediation, health care systems and
additional infrastructure for Petroecuador. The engineer’s
report also asserted that an additional $8.4 billion could
be
16
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
assessed against Chevron for unjust enrichment. In 2009,
following the disclosure by Chevron of evidence that the judge
participated in meetings in which businesspeople and individuals
holding themselves out as government officials discussed the
case and its likely outcome, the judge presiding over the case
was recused. In 2010, Chevron moved to strike the mining
engineer’s report and to dismiss the case based on evidence
obtained through discovery in the United States indicating that
the report was prepared by consultants for the plaintiffs before
being presented as the mining engineer’s independent and
impartial work and showing further evidence of misconduct. In
August 2010, the judge issued an order stating that he was not
bound by the mining engineer’s report and requiring the
parties to provide their positions on damages within
45 days. Chevron subsequently petitioned for recusal of the
judge, claiming that he had disregarded evidence of fraud and
misconduct and that he had failed to rule on a number of motions
within the statutory time requirement.
In September 2010, Chevron submitted its position on damages,
asserting that no amount should be assessed against it. The
plaintiffs’ submission, which relied in part on the mining
engineer’s report, took the position that damages are
between approximately $16 billion and $76 billion and
that unjust enrichment should be assessed in an amount between
approximately $5 billion and $38 billion. The next
day, the judge issued an order closing the evidentiary phase of
the case and notifying the parties that he had requested the
case file so that he could prepare a judgment. Chevron
petitioned to have that order declared a nullity in light of
Chevron’s prior recusal petition, and because procedural
and evidentiary matters remain unresolved. In October 2010,
Chevron’s motion to recuse the judge was granted. A new
judge has taken charge of the case, and that judge has revoked
the prior judge’s order closing the evidentiary phase of
the case.
Chevron cannot predict the timing or content of future
developments in the Lago Agrio litigation, and a judgment could
be entered at any time. Chevron will continue a vigorous defense
of any attempted imposition of liability. In the event of an
adverse trial court judgment, Chevron would expect to pursue its
appeals in Ecuador. Because Chevron has no substantial assets in
Ecuador, Chevron would expect enforcement actions following any
adverse judgment to be brought in other jurisdictions. Chevron
would expect to contest any such actions. The ultimate outcome,
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 2008 engineer’s report and the
September 2010 plaintiffs’ submission, management does not
believe those 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).
| Note 12. | Other Contingencies and Commitments |
Guarantees
The company and its subsidiaries have certain
other contingent liabilities with respect to guarantees, direct
or indirect, of debt of affiliated companies or third parties.
Under the terms of the guarantee arrangements, generally the
company would be required to perform should the affiliated
company or third party fail to fulfill its obligations under the
arrangements. In some cases, the guarantee arrangements may have
recourse provisions that would enable the company to recover any
payments made under the terms of the guarantees from assets
provided as collateral.
Off-Balance-Sheet Obligations
The company and its
subsidiaries have certain other contingent liabilities relating
to long-term unconditional purchase obligations and commitments,
including throughput and
take-or-pay
agreements, some of which relate to suppliers’ financing
arrangements. The agreements typically provide goods and
services, such as pipeline and storage capacity, drilling rigs,
utilities, and petroleum products, to be used or sold in the
ordinary course of the company’s business.
Indemnifications
The company provided certain indemnities
of contingent liabilities of Equilon and Motiva to Shell and
Saudi Refining, Inc., in connection with the February 2002 sale
of the company’s interests in those investments. The
company would be required to perform if the indemnified
liabilities become actual losses. Were that to occur, the
company could be required to make future payments up to
$300 million. Through September 2010, the company
17
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
paid $48 million under these indemnities and continues to
be obligated for possible additional indemnification payments in
the future.
The company has also provided indemnities relating to contingent
environmental liabilities related to assets originally
contributed by Texaco to the Equilon and Motiva joint ventures
and environmental conditions that existed prior to the formation
of Equilon and Motiva or that occurred during the period of
Texaco’s ownership interest in the joint ventures. In
general, the environmental conditions or events that are subject
to these indemnities must have arisen prior to December 2001.
Claims had to be asserted by February 2009 for Equilon
indemnities and must be asserted no later than February 2012 for
Motiva indemnities. Under the terms of these indemnities, there
is no maximum limit on the amount of potential future payments.
In February 2009, Shell delivered a letter to the company
purporting to preserve unmatured claims for certain Equilon
indemnities. The letter itself provides no estimate of the
ultimate claim amount. Management does not believe this letter
or any other information provides a basis to estimate the
amount, if any, of a range of loss or potential range of loss
with respect to either the Equilon or the Motiva indemnities.
The company posts no assets as collateral and has made no
payments under the indemnities.
The amounts payable for the indemnities described in the
preceding paragraph are to be net of amounts recovered from
insurance carriers and others and net of liabilities recorded by
Equilon or Motiva prior to September 30, 2001, for any
applicable incident.
In the acquisition of Unocal, the company assumed certain
indemnities relating to contingent environmental liabilities
associated with assets that were sold in 1997. The acquirer of
those assets shared in certain environmental remediation costs
up to a maximum obligation of $200 million, which had been
reached at December 31, 2009. Under the indemnification
agreement, after reaching the $200 million obligation,
Chevron is solely responsible until April 2022, when the
indemnification expires. The environmental conditions or events
that are subject to these indemnities must have arisen prior to
the sale of the assets in 1997.
Although the company has provided for known obligations under
this indemnity that are probable and reasonably estimable, the
amount of additional future costs may be material to results of
operations in the period in which they are recognized. The
company does not expect these costs will have a material effect
on its consolidated financial position or liquidity.
Environmental
The company is subject to loss
contingencies pursuant to laws, regulations, private claims and
legal proceedings related to environmental matters that are
subject to legal settlements or that in the future may require
the company to take action to correct or ameliorate the effects
on the environment of prior release of chemicals or petroleum
substances, including MTBE, by the company or other parties.
Such contingencies may exist for various sites, including, but
not limited to, federal Superfund sites and analogous sites
under state laws, refineries, crude oil fields, service
stations, terminals, land development areas, and mining
operations, whether operating, closed or divested. These future
costs are not fully determinable due to such factors as the
unknown magnitude of possible contamination, the unknown timing
and extent of the corrective actions that may be required, the
determination of the company’s liability in proportion to
other responsible parties, and the extent to which such costs
are recoverable from third parties.
Although the company has provided for known environmental
obligations that are probable and reasonably estimable, the
amount of additional future costs may be material to results of
operations in the period in which they are recognized. The
company does not expect these costs will have a material effect
on its consolidated financial position or liquidity. Also, the
company does not believe its obligations to make such
expenditures have had, or will have, any significant impact on
the company’s competitive position relative to other
U.S. or international petroleum or chemical companies.
Financial Instruments
The company believes it has no
material market or credit risks to its operations, financial
position or liquidity as a result of its commodities and other
derivative activities.
Equity Redetermination
For crude oil and natural gas
producing operations, ownership agreements may provide for
periodic reassessments of equity interests in estimated crude
oil and natural gas reserves. These activities, individually or
together, may result in gains or losses that could be material
to earnings in any given period.
18
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
One such equity redetermination process has been under way since
1996 for Chevron’s interests in four producing zones at the
Naval Petroleum Reserve at Elk Hills, California, for the time
when the remaining interests in these zones were owned by the
U.S. Department of Energy. A wide range remains for a
possible net settlement amount for the four zones. For this
range of settlement, Chevron estimates its maximum possible net
before-tax liability at approximately $200 million, and the
possible maximum net amount that could be owed to Chevron is
estimated at about $150 million. The timing of the
settlement and the exact amount within this range of estimates
are uncertain.
Other Contingencies
On April 26, 2010, a California
appeals court issued a ruling related to the adequacy of an
Environmental Impact Report (EIR) supporting the issuance of
certain permits by the city of Richmond, California, to replace
and upgrade certain facilities at Chevron’s refinery in
Richmond. The parties to the case have stipulated that entry of
final judgment by the trial court be postponed pending on-going
settlement discussions. The company continues to evaluate its
options going forward, which may include settlement, requesting
the city to revise the EIR to address the issues identified by
the Court of Appeal or other actions. Management believes the
outcomes associated with the potential options for the project
are uncertain. Due to the uncertainty of the company’s
future course of action, or potential outcomes of any action or
combination of actions, management does not believe an estimate
of the financial effects, if any, of the ruling can be made at
this time. However, the company’s ultimate exposure may be
significant to net income in any one future period.
Chevron receives claims from and submits claims to customers;
trading partners; U.S. federal, state and local regulatory
bodies; governments; contractors; insurers; and suppliers. The
amounts of these claims, individually and in the aggregate, may
be significant and take lengthy periods to resolve.
The company and its affiliates also continue to review and
analyze their operations and may close, abandon, sell, exchange,
acquire or restructure assets to achieve operational or
strategic benefits and to improve competitiveness and
profitability. These activities, individually or together, may
result in gains or losses in future periods.
| Note 13. | Fair Value Measurements |
Accounting standards for fair value measurement (ASC
820) establish a framework for measuring fair value and
stipulate disclosures about fair value measurements. The
standards apply to recurring and nonrecurring financial and
nonfinancial assets and liabilities that require or permit fair
value measurements. Among the required disclosures is the fair
value hierarchy of inputs the company uses to value an asset or
a liability. The three levels of the fair value hierarchy are
described as follows:
Level 1: Quoted prices (unadjusted) in active markets
for identical assets and liabilities. For the com-
pany, 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.
pany, 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.
19
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
The fair value hierarchy for recurring assets and liabilities
measured at fair value at September 30, 2010 and
December 31, 2009, is as follows:
Assets
and Liabilities Measured at Fair Value on a Recurring
Basis
|
Prices in
|
Prices in
|
|||||||||||||||||||||||||||||||
|
Active
|
Active
|
|||||||||||||||||||||||||||||||
|
Markets for
|
Markets for
|
|||||||||||||||||||||||||||||||
|
Identical
|
Other
|
Identical
|
Other
|
|||||||||||||||||||||||||||||
|
At
|
Assets/
|
Observable
|
Unobservable
|
At
|
Assets/
|
Observable
|
Unobservable
|
|||||||||||||||||||||||||
|
September 30
|
Liabilities
|
Inputs
|
Inputs
|
December 31
|
Liabilities
|
Inputs
|
Inputs
|
|||||||||||||||||||||||||
| 2010 | (Level 1) | (Level 2) | (Level 3) | 2009 | (Level 1) | (Level 2) | (Level 3) | |||||||||||||||||||||||||
| (Millions of dollars) | ||||||||||||||||||||||||||||||||
|
Assets
|
||||||||||||||||||||||||||||||||
|
Marketable Securities
|
$ 66 | $ 66 | $ — | $ — | $106 | $106 | $ — | $— | ||||||||||||||||||||||||
|
Derivatives
|
154 | 21 | 133 | — | 127 | 14 | 113 | — | ||||||||||||||||||||||||
|
Total Recurring Assets at Fair Value
|
$220 | $ 87 | $133 | $ — | $233 | $120 | $113 | $— | ||||||||||||||||||||||||
|
Liabilities
|
||||||||||||||||||||||||||||||||
|
Derivatives
|
$175 | $143 | $ 32 | $ — | $101 | $ 20 | $ 81 | $— | ||||||||||||||||||||||||
|
Total Recurring Liabilities at Fair Value
|
$175 | $143 | $ 32 | $ — | $101 | $ 20 | $ 81 | $— | ||||||||||||||||||||||||
Marketable Securities
The company calculates fair value
for its marketable securities based on quoted market prices for
identical assets and liabilities. The fair values reflect the
cash that would have been received if the instruments were sold
at September 30, 2010.
Derivatives
The company records its derivative
instruments — other than any commodity derivative
contracts that are designated as normal purchase and normal
sale — on the Consolidated Balance Sheet at fair
value, with virtually all the offsetting amount to the
Consolidated Statement of Income. For derivatives with identical
or similar provisions as contracts that are publicly traded on a
regular basis, the company uses the market values of the
publicly traded instruments as an input for fair value
calculations.
The company’s derivative instruments principally include
crude oil, natural gas and refined product futures, swaps,
options and forward contracts. Derivatives classified as
Level 1 include futures, swaps and options contracts traded
in active markets such as the New York Mercantile Exchange.
Derivatives classified as Level 2 include swaps, options,
and forward contracts principally with financial institutions
and other oil and gas companies, the fair values for which are
obtained from third-party broker quotes, industry pricing
services and exchanges. The company obtains multiple sources of
pricing information for the Level 2 instruments. Since this
pricing information is generated from observable market data, it
has historically been very consistent. The company does not
materially adjust this information. The company incorporates
internal review, evaluation and assessment procedures, including
a comparison of Level 2 fair values derived from the
company’s internally developed forward curves (on a sample
basis) with the pricing information to document reasonable,
logical and supportable fair value determinations and proper
level of classification.
Impairments of “Properties, plant and equipment”
Assets measured at fair value on a nonrecurring basis were
not material to the company’s financial position, results
of operations or liquidity in the three- and nine-month periods
of 2010. Before-tax losses associated with the impairment of
property, plant and equipment held and used and held for sale in
the third quarter 2009 were $93 million and nil,
respectively, and for the nine months ended September 30,
2009, were $358 million and $92 million, respectively.
The losses in 2009 were the result of fair values determined
both 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, and from bids received from
prospective buyers of assets held for sale.
20
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
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 $11.0 billion and $8.7 billion
at September 30, 2010 and December 31, 2009,
respectively. The instruments held in “Time deposits”
are bank time deposits with maturities greater than
90 days, and had carrying/fair values of $3.5 billion
at September 30, 2010. The fair values of cash, cash
equivalents and bank time deposits reflect the cash that would
have been received or paid if the instruments were settled at
September 30, 2010.
“Cash and cash equivalents” does not include
investments with a carrying/fair value of $186 million and
$123 million at September 30, 2010 and
December 31, 2009, respectively. These investments are
restricted funds related to an international upstream
development project and Pascagoula Refinery projects, which are
reported in “Deferred charges and other assets” on the
Consolidated Balance Sheet. Long-term debt of $5.6 billion
and $5.7 billion had estimated fair values of
$6.5 billion and $6.2 billion at September 30,
2010 and December 31, 2009, respectively.
Fair values of other financial instruments at September 30,
2010 were not material.
| Note 14. | Derivative Instruments and Hedging Activities |
The company’s derivative instruments principally include
crude oil, natural gas and refined product futures, swaps,
options and forward contracts. None of the company’s
derivative instruments are designated as a hedging instrument,
although certain of the company’s affiliates make such
designation. The company’s derivatives are not material to
the company’s 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
September 30, 2010 and December 31, 2009, 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
Fair Value of Derivatives Not Designated as Hedging Instruments
|
Asset Derivatives —
|
Liability Derivatives —
|
|||||||||||||||||||
| Fair Value | Fair Value | |||||||||||||||||||
|
Type of
|
At
|
At
|
(Millions of Dollars)
|
At
|
At
|
|||||||||||||||
|
Derivative
|
Balance Sheet
|
September 30
|
December 31
|
Balance Sheet
|
September 30
|
December 31
|
||||||||||||||
| Contract | Classification | 2010 | 2009 | Classification | 2010 | 2009 | ||||||||||||||
|
Commodity
|
Accounts and notes receivable, net | $ 85 | $ 99 | Accounts payable | $125 | $ 73 | ||||||||||||||
|
Commodity |
Long-term receivables, net |
69 | 28 | Deferred credits and other noncurrent obligations | 50 | 28 | ||||||||||||||
| $154 | $127 | $175 | $101 | |||||||||||||||||
Consolidated
Statement of Income:
The Effect of Derivatives Not Designated as Hedging Instruments
The Effect of Derivatives Not Designated as Hedging Instruments
|
Gain/(Loss)
|
Gain/(Loss)
|
|||||||||||||||||
|
Three Months
|
Nine Months
|
|||||||||||||||||
|
Ended
|
Ended
|
|||||||||||||||||
| September 30 | September 30 | |||||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||||
|
Type
of
|
||||||||||||||||||
| Derivative Contract | Statement of Income Classification | (Millions of dollars) | ||||||||||||||||
|
Foreign Exchange
|
Other income | $ — | $ 8 | $ — | $ 26 | |||||||||||||
|
Commodity
|
Sales and other operating revenues | (58 | ) | 32 | 94 | (63 | ) | |||||||||||
|
Commodity
|
Purchased crude oil and products | (12 | ) | (18 | ) | (38 | ) | (295 | ) | |||||||||
|
Commodity
|
Other income | 7 | 8 | (2 | ) | 1 | ||||||||||||
| $(63 | ) | $ 30 | $ 54 | $(331 | ) | |||||||||||||
21
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
| Note 15. | New Accounting Standards |
Transfers and Servicing (ASC 860), Accounting for Transfers
of Financial Assets (ASU
2009-16)
The FASB issued ASU
2009-16
in
December 2009. This standard became effective for the company on
January 1, 2010. ASU
2009-16
changes how companies account for transfers of financial assets
and eliminates the concept of qualifying special-purpose
entities. Adoption of the guidance did not have an effect on the
company’s results of operations, financial position or
liquidity.
Consolidation (ASC 810), Improvements to Financial Reporting
by Enterprises Involved With Variable Interest Entities (ASU
2009-17)
The FASB issued ASU
2009-17
in
December 2009. This standard became effective for the company on
January 1, 2010. ASU
2009-17
requires the enterprise to qualitatively assess if it is the
primary beneficiary of a variable-interest entity (VIE), and, if
so, the VIE must be consolidated. Adoption of the standard did
not have an impact on the company’s results of operations,
financial position or liquidity.
Receivables (ASC 310), Disclosures about the Credit Quality
of Financing Receivables and the Allowance for Credit Losses
(ASU
2010-20)
In July 2010, the FASB issued ASU
2010-20,
which becomes effective with the company’s reporting at
December 31, 2010. This standard amends and expands
disclosure requirements about the credit quality of financing
receivables and the related allowance for credit losses. As a
result of these amendments, companies are required to
disaggregate, by portfolio segment or class of financing
receivable, certain existing disclosures and provide certain new
disclosures about financing receivables and related allowance
for credit losses. The company does not anticipate changes to
its existing disclosures when the standard becomes effective.
| Note 16. | 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. As originally announced, approximately
3,200 employees in the refining, marketing, and supply and
trading operations, and 600 employees from corporate
staffs, were expected to be terminated under the programs. Due
to redeployment efforts within the company, total employee
terminations under the programs are expected to be reduced from
approximately 3,800 employees to approximately
3,600 employees. About 1,700 of the affected positions are
located in the United States. It is anticipated that
2,400 employees of the total covered under the programs
will be terminated during 2010, and the programs are expected to
be completed by the end of 2011. About 600 employees have
been terminated to date.
A before-tax charge of $244 million ($175 million
after-tax) was recorded in the first quarter 2010, with
$191 million reported as “Operating expenses” and
$53 million as “Selling, general and administrative
expenses” on the Consolidated Statement of Income. The
accrued liability is classified as current on the Consolidated
Balance Sheet. Approximately $80 million ($50 million
after-tax) is associated with terminations in the
U.S. Downstream, $127 million ($100 million
after-tax) in International Downstream and $37 million
($25 million after-tax) in All Other.
22
Table of Contents
NOTES TO
CONSOLIDATED FINANCIAL
STATEMENTS — (Continued)
During the second and third quarters of 2010, the company made
payments of $35 million associated with these liabilities.
The majority of the payments were in Downstream.
| Amounts Before Tax | ||||
| (Millions of dollars) | ||||
|
Balance at January 1, 2010
|
$ — | |||
|
Accruals
|
244 | |||
|
Adjustments
|
(3 | ) | ||
|
Payments
|
(35 | ) | ||
|
Balance at September 30, 2010
|
$206 | |||
| Note 17. | Asset Retirement Obligations |
At September 30, 2010, the company’s liability for
asset retirement obligations calculated in accordance with
accounting standards for asset retirement obligations (ASC
410) was approximately $11.4 billion, compared with
$10.2 billion at year-end 2009. The $1.2 billion net
increase reflects increasing costs to abandon wells, equipment
and facilities.
23
Table of Contents
| Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations |
Third
Quarter 2010 Compared with Third Quarter 2009
And Nine Months 2010 Compared with Nine Months 2009
And Nine Months 2010 Compared with Nine Months 2009
Key
Financial Results
Earnings
by Business Segment
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Upstream(1)
|
||||||||||||||||
|
United States
|
$ 946 | $ 889 | $ 3,192 | $1,196 | ||||||||||||
|
International
|
2,618 | 2,847 | 9,638 | 5,575 | ||||||||||||
|
Total Upstream
|
3,564 | 3,736 | 12,830 | 6,771 | ||||||||||||
|
Downstream(1)
|
||||||||||||||||
|
United States
|
349 | 127 | 864 | 212 | ||||||||||||
|
International
|
216 | 135 | 872 | 934 | ||||||||||||
|
Total Downstream
|
565 | 262 | 1,736 | 1,146 | ||||||||||||
|
Total Segment Earnings
|
4,129 | 3,998 | 14,566 | 7,917 | ||||||||||||
|
All Other
|
(361 | ) | (167 | ) | (837 | ) | (504 | ) | ||||||||
|
Net Income Attributable to Chevron Corporation(2)(3)
|
$3,768 | $3,831 | $13,729 | $7,413 | ||||||||||||
|
|
||||||||||||||||
|
(1) 2009 information has been revised to conform with the
2010 segment presentation.
|
||||||||||||||||
|
(2) Includes foreign currency effects
|
$ (367 | ) | $ (170 | ) | $ (324 | ) | $ (677 | ) | ||||||||
|
(3) Also referred to as “earnings” in the
discussions that follow.
|
||||||||||||||||
Net income attributable to Chevron Corporation
for the
third quarter 2010 was $3.77 billion ($1.87 per
share — diluted), compared with $3.83 billion
($1.92 per share — diluted) in the corresponding 2009
period. Net income attributable to Chevron Corporation for the
first nine months of 2010 was $13.73 billion ($6.84 per
share — diluted), versus $7.41 billion ($3.71 per
share — diluted) in the first nine months of 2009.
The activities reported in Chevron’s upstream and
downstream operating segments have changed effective
January 1, 2010. Results for the chemicals businesses are
now reported as part of the downstream segment. In addition, the
company’s significant upstream-enabling operations,
primarily a
gas-to-liquids
project and major international export pipelines, have been
reclassified from the downstream segment to the upstream
segment. Prior period information in this report has been
revised to conform to the 2010 presentation.
Upstream
earnings in the third quarter 2010 were
$3.56 billion, compared with $3.74 billion in the 2009
quarter. The decrease was primarily associated with the absence
of gains on asset sales and tax items related to Gorgon project
in Australia in the third quarter of 2009. Earnings for the
first nine months of 2010 were $12.83 billion, versus
$6.77 billion a year earlier. The increase between periods
was mainly due to higher prices for crude oil and natural gas
and increased production of crude oil.
Downstream
earnings were $565 million in the third
quarter 2010, compared with $262 million in the
year-earlier period. Earnings for the first nine months of 2010
were $1.74 billion, versus $1.15 billion in the
corresponding 2009 period. The increase between both comparative
periods was mainly associated with improved margins on refined
products, and higher earnings from chemicals
operations — largely from the 50 percent-owned
Chevron Phillips Chemical Company LLC. Also contributing to the
increase in the 2010 nine-month period was a favorable swing in
24
Table of Contents
mark-to-market
effects on derivative instruments. Earnings for the first nine
months of 2009 included $540 million of gains on sales of
marketing businesses outside the United States.
Refer to pages 29 through 32 for additional discussion of
results by business segment and “All Other” activities
for the third quarter and first nine months of 2010 versus the
same periods in 2009.
Business
Environment and Outlook
Chevron is a global energy company with significant business
activities in the following countries: Angola, Argentina,
Australia, Azerbaijan, Bangladesh, Brazil, Cambodia, Canada,
Chad, China, Colombia, Democratic Republic of the Congo,
Denmark, Indonesia, Kazakhstan, Myanmar, the Netherlands,
Nigeria, Norway, the Partitioned Zone between Saudi Arabia and
Kuwait, the Philippines, Republic of the Congo, Singapore, South
Africa, South Korea, Thailand, Trinidad and Tobago, the United
Kingdom, the United States, Venezuela, and Vietnam.
Earnings of the company depend largely on the profitability of
its upstream 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 company’s 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 company’s operations, especially upstream, can also be
affected by changing economic, regulatory and political
environments in the various countries in which it operates,
including the United States. Civil unrest, acts of violence or
strained relations between a government and the company or other
governments may impact the company’s operations or
investments. Those developments have at times significantly
affected the company’s operations and results and are
carefully considered by management when evaluating the level of
current and future activity in such countries.
To sustain its long-term competitive position in the upstream
business, the company must develop and replenish an inventory of
projects that offer 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 company’s
current operations or future prospects.
The company also continually evaluates opportunities to dispose
of assets that are not expected to provide sufficient long-term
value or to acquire assets or operations complementary to its
asset base to help augment the company’s financial
performance and growth. 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 company’s operating expenses
and capital programs for all business segments, but particularly
for upstream. Softening of these cost pressures started in late
2008 and continued through most of 2009. Industry costs began to
level out in the fourth quarter 2009 and rose slightly in 2010.
The company continues to actively manage its schedule of work,
contracting, procurement and supply-chain activities to
effectively manage costs. (Refer to the “Upstream”
section below for a discussion of the trend in crude oil prices.)
The company closely monitors developments in the financial and
credit markets, the level of worldwide economic activity and the
implications to the company of movements in prices for crude oil
and natural gas. Management 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 36.)
25
Table of Contents
Comments related to earnings trends for the company’s major
business areas are as follows:
Upstream
Earnings for the upstream segment are
closely aligned with industry price levels for crude oil and
natural gas. Crude oil and natural gas prices are subject to
external factors over which the company has no control,
including product demand connected with global economic
conditions, industry inventory levels, production quotas imposed
by the Organization of Petroleum Exporting Countries (OPEC),
weather-related damage and disruptions, competing fuel prices,
and regional supply interruptions or fears thereof that may be
caused by military conflicts, civil unrest or political
uncertainty. Moreover, any of these factors could also inhibit
the company’s production capacity in an affected region.
The company monitors developments closely in the countries in
which it operates and holds investments, and attempts to manage
risks in operating its facilities and businesses. Besides the
impact of the fluctuation in prices for crude oil and natural
gas, the longer-term trend in earnings for the upstream segment
is also a function of other factors, including the
company’s ability to find or acquire and efficiently
produce crude oil and natural gas, changes in fiscal terms of
contracts and changes in tax laws and regulations.
Price levels for capital and exploratory costs and operating
expenses associated with the production of crude oil and natural
gas can also be subject to external factors beyond the
company’s control. External factors include not only the
general level of inflation but also commodity prices and prices
charged by the industry’s material and service providers,
which can be affected by the volatility of the industry’s
own
supply-and-demand
conditions for such materials and services. Capital and
exploratory expenditures and operating expenses also can be
affected by damage to production facilities caused by severe
weather or civil unrest.
The chart below shows the trend in benchmark prices for West
Texas Intermediate (WTI) crude oil and U.S. Henry Hub
natural gas. During 2009, industry price levels for WTI ranged
from $34 to $81 per barrel and finished the year at $79 per
barrel. The WTI price in the first nine months of 2010 averaged
$78 and ended October at $81.
|
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 nine months | |
| of 2010 primarily due to greater availability of lower quality crudes. 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 35 for the company’s average U.S. and international crude oil realizations.) | ||
In contrast to price movements in the global market for crude
oil, price changes for natural gas in many regional markets are
more closely aligned with
supply-and-demand
conditions in those markets. In the United States, prices at
Henry Hub averaged about $4.60 per thousand cubic feet (MCF) in
the first nine months of 2010, compared with about $3.50 during
the first nine months of 2009. At the end of October 2010, the
Henry Hub spot price was about $3.40 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 company’s production of natural gas in
these locations. Chevron continues to invest in long-term
projects in these locations to install infrastructure to produce
and liquefy natural gas for transport by tanker to other markets
where greater demand results in higher prices. International
natural gas realizations averaged about $4.60 per MCF during the
first nine months of 2010, compared with about $4.00 in the same
period last year. (See page 35 for the company’s
average natural gas realizations for the U.S. and
international regions.)
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Table of Contents
The company’s worldwide net oil-equivalent production in
the first nine months of 2010 averaged 2.755 million
barrels per day. During the period, about one-fifth of the
company’s net oil-equivalent production occurred in the
OPEC-member countries of Angola, Nigeria and Venezuela and in
the Partitioned Zone between Saudi Arabia and Kuwait. OPEC
quotas had no effect on the company’s net crude oil
production for the first nine months of 2010, while production
during the first nine months of 2009 was reduced by
approximately 27,000 barrels per day due to quota
limitations. Curtailments by OPEC did not constrain the
company’s production in the third quarter 2009. At the most
recent meeting in October 2010, members of OPEC supported
maintaining production quotas in effect since December 2008.
The full-year outlook for oil-equivalent production based on the
nine-month 2010 average price of $78 per barrel is estimated at
2.75 million barrels per day. This estimate is subject to
many factors and uncertainties, including additional quotas that
may be imposed by OPEC, price effects on production volumes
calculated under 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. 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 Chevron’s upstream
investment is made outside the United States.
Gulf of Mexico Update
In April 2010, an accident occurred
on the Transocean Deepwater Horizon, a deepwater drilling rig in
the Gulf of Mexico, resulting in loss of life, the sinking of
the rig and a significant oil spill. The rig was drilling an
exploratory well at the BP-operated Macondo prospect. Chevron
was not a participant in the well. Subsequent to the event, the
U.S. Department of the Interior suspended drilling of wells
using subsea blowout preventers (BOPs) or surface BOPs on a
floating facility in the Gulf of Mexico and the Pacific regions.
On October 12, 2010, the Secretary of the Interior lifted
the suspension on deepwater drilling activity, provided that
operators certify compliance with all rules and requirements,
including availability of adequate blowout containment resources.
The suspension has created delays in shallow water permitting
and delayed the drilling of some exploratory deepwater wells as
well as impacted development drilling at the recently
commissioned, nonoperated Perdido project. The company does not
expect there to be a material impact on production for the full
year 2010. The company has submitted one deepwater drilling
permit application and plans to submit several additional
applications over the next few months. Two deepwater drilling
rigs are on stand-by, pending issuance of permits from the
U.S. Bureau of Ocean Energy Management (BOEM), Regulation,
and Enforcement to drill wells in the Gulf of Mexico. A third
deepwater drill rig has received a permit to drill a water
injection well at the Tahiti Field. The future effects of this
incident, including any new or additional regulations that may
be adopted in response, 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.
As previously announced, Chevron and several other companies
plan to build and deploy a rapid response system that will be
available to capture and contain crude oil in the event of a
future well blowout in the deepwater Gulf of Mexico. The new
system will be engineered to be used in water depths up to
10,000 feet and designed to have initial capacity to
contain 100,000 barrels per day, with potential for
expansion. The companies committed to equally fund the initial
$1 billion investment in the system. There will be
additional ongoing costs for operations and maintenance of the
system components. An initial agreement to secure underwater
well containment equipment for industry use has been announced,
and other equipment is expected to be secured and available in
the coming months with the new system targeted for completion
within 18 months. The companies intend to form a non-profit
organization, the Marine Well Containment Company, to operate
and maintain this system. Other companies will be invited and
encouraged to participate in this organization.
Refer to the “Results of Operations” section on pages
29-31
for
additional discussion of the company’s upstream business.
27
Table of Contents
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 refinery crude oil feedstocks, petrochemical
feedstocks and fuel costs. 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 company’s
refining and marketing network, the effectiveness of the crude
oil and product-supply functions and the volatility of
tanker-charter rates for the company’s shipping operations,
which are driven by the industry’s demand for crude oil and
product tankers. Other factors beyond the company’s control
include the general level of inflation and energy costs to
operate the company’s refinery and distribution network.
The company’s most significant marketing areas are the West
Coast of North America, the U.S. Gulf Coast, Latin America,
Asia, southern Africa and the United Kingdom. Chevron operates
or has significant ownership interests in refineries in each of
these areas except Latin America. In the third quarter 2010, the
company discontinued sales of Chevron- and Texaco-branded motor
fuels in the District of Columbia, Delaware, Indiana, Kentucky,
North Carolina, New Jersey, Maryland, Ohio, Pennsylvania, South
Carolina, Virginia, West Virginia and parts of Tennessee, where
the company sold to retail customers through approximately 1,100
stations and to commercial and industrial customers through
supply arrangements. During 2009, sales in these markets
represented approximately 8 percent of the company’s
total U.S. retail fuel sales volumes. Additionally, in
January 2010, the company sold the rights to the Gulf trademark
in the United States and its territories that it had previously
licensed for use in the U.S. Northeast and Puerto Rico.
The company’s refining and marketing margins in third
quarter 2010 improved over the same period in 2009, but remain
relatively weak due to the economic slowdown, excess refined
product supplies and surplus refining capacity. Expecting these
conditions to continue for several years, in the 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. As of
third quarter, it is expected that approximately 3,200 positions
in the downstream operations will be eliminated under the
programs. About 1,300 of the affected positions are located in
the United States. It is anticipated that 2,000 positions will
be eliminated during 2010, and the programs are expected to be
completed by the end of 2011. Refer to Note 16 of the
Consolidated Financial Statements, beginning on page 22,
for further discussion. The company is also soliciting bids for
13 U.S. terminals and certain operations in Europe
(including the company’s Pembroke Refinery), the Caribbean
and select Central America markets, and is in negotiations to
divest certain operations in Africa. These potential market
exits, dispositions of assets, and other actions may result in
gains or losses in future periods. In October 2010, the company
completed the sale of five of the 13 targeted
U.S. terminals. The gain will be reflected in the fourth
quarter 2010 results and is not expected to be material.
Refer to the “Results of Operations” section on pages
31-32
for
additional discussion of the company’s 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 the first quarter 2010,
employee-reduction programs were announced for the corporate
staffs. As of third quarter, it is expected that approximately
400 positions from the corporate staffs will be eliminated under
the programs by the end of 2011, most of which will be
eliminated during 2010. Refer to Note 16 of the
Consolidated Financial Statements, beginning on page 22,
for further discussion.
28
Table of Contents
Operating
Developments
Recent achievements for upstream projects include:
| • | United States — Sanctioned development of the Jack/St. Malo project, the company’s first operated project located in the Lower Tertiary trend in the deepwater Gulf of Mexico. Seven exploration and appraisal wells have been successfully and safely drilled at these fields since 2003. Chevron has a working interest of 50 percent in the Jack Field, 51 percent in the St. Malo Field and 50.7 percent for the host facility. |
| • | China — Acquired a 100 percent interest in Blocks 53-30 and 64-18, and a 59 percent interest in Block 42-05, covering a combined total exploratory acreage of approximately 8,100 square miles (21,000 sq km) in the South China Sea’s Pearl River Mouth Basin. |
| • | Liberia — Acquired a 70 percent interest and operatorship in three deepwater concessions covering 3,700 square miles (9,600 sq km) off the coast of Liberia in western Africa. A three-year exploratory program is expected to begin in the fourth quarter of this year. |
| • | Turkey — Signed a Joint Operation Agreement with Turkey’s state oil company for an exploration license in the Black Sea. Chevron acquired a 50 percent interest in a western portion of License 3921, an 8,700 square mile (22,505 sq km) block located 220 miles (350 km) northwest of the capital city of Ankara. |
| • | Australia — Announced two deepwater natural gas discoveries in the Carnarvon Basin offshore Western Australia, Brederode-1 in 50 percent-owned Block WA-364-P and Acme-1 in 67 percent-owned Block WA-205-P. These discoveries are expected to contribute to future growth at company-operated liquefied natural gas (LNG) projects in Australia. |
In the downstream business, a new, 60,000 barrel per day
heavy oil hydrocracker, which maximizes the yield of
transportation fuels from heavy crude oil, was commissioned and
reached full capacity in the third quarter at the
50 percent-owned GS Caltex Yeosu Refinery in South Korea.
Additionally, the company announced in October that a
wholly-owned subsidiary, Chevron Pipe Line Co., has sold its
23.4 percent ownership interest in the Colonial Pipeline
Co. The financial effects of the sale will be reflected in
results for the fourth quarter 2010. The company also continued
to progress restructuring plans to streamline its operations.
Results
of Operations
Business Segments
The following section presents the
results of operations for the company’s business
segments — Upstream and Downstream — as well
as for “All Other” — the departments and
companies managed at the corporate level. (Refer to Note 5
beginning on page 9 for a discussion of the company’s
“reportable segments,” as defined under the accounting
standards for segment reporting.)
Upstream
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
U.S. Upstream Earnings
|
$946 | $889 | $3,192 | $1,196 | ||||||||||||
U.S. upstream earnings of $946 million in the third
quarter of 2010 increased $57 million from the same period
last year. Higher crude oil and natural gas realizations
increased earnings by $290 million, and lower exploration
expense in the third quarter of 2010 benefited earnings by
$40 million. Partially offsetting these effects were higher
operating expenses of $150 million between periods, in part
due to the Gulf of Mexico drilling moratorium, and lower net
oil-equivalent production in the 2010 period, which reduced
earnings by about $120 million.
Earnings for the first nine months of 2010 were approximately
$3.19 billion, up about $2 billion from the
corresponding period in 2009. Higher prices for crude oil and
natural gas increased earnings by about $1.92 billion
between periods, and an increase in net oil-equivalent
production in the 2010 period benefited income by about
$140 million. Other items of lesser significance were
largely offsetting between periods.
29
Table of Contents
The average realization per barrel for crude oil and natural gas
liquids in the third quarter of 2010 was approximately $69,
compared with $60 a year earlier. For the nine-month periods,
average realizations were about $70 and $50 for 2010 and 2009,
respectively. The average natural gas realization in the third
quarter 2010 was $4.06 per thousand cubic feet, compared with
$3.28 in the year-ago period. The average nine-month
realizations were $4.47 in 2010 and $3.56 in 2009.
Net oil-equivalent production of 692,000 barrels per day in
the third quarter 2010 was down 53,000 barrels per day, or
7 percent, from the corresponding period in 2009. The
decrease in production was associated with normal field declines
and downtime for maintenance and repairs.
Nine-month 2010 production was 711,000 barrels per day, up
slightly from the 2009 period. Increased production from the
Tahiti Field was mostly offset by natural field declines. The
net liquids component of oil-equivalent production was 482,000
and 492,000 barrels per day for the third quarter and nine
month periods of 2010, 5 percent lower and 4 percent
higher than the corresponding 2009 periods, respectively. Net
natural gas production of 1.26 billion cubic feet per day
in the third quarter 2010 and 1.32 billion cubic feet per
day in first nine months of 2010 decreased 12 percent and
6 percent from the comparative 2009 periods.
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
International Upstream Earnings*
|
$2,618 | $2,847 | $9,638 | $5,575 | ||||||||||||
|
|
||||||||||||||||
|
* Includes foreign currency effects
|
$ (245 | ) | $ (89 | ) | $ (240 | ) | $ (522 | ) | ||||||||
International upstream earnings of $2.62 billion in the
third quarter 2010 decreased $229 million from the
corresponding period in 2009. Higher prices and sales volumes
for crude oil and natural gas benefited earnings by
$860 million, and favorable tax items increased earnings by
$170 million between periods. However, this net benefit was
more than offset by higher depreciation, exploration and
operating expenses of $630 million in the 2010 period, and
the absence of about $400 million of gains on asset sales
and tax items related to the Gorgon project in Australia
recognized in the third quarter 2009. Foreign currency effects
decreased earnings by $245 million in the 2010 quarter,
compared with a decrease of $89 million a year earlier.
Earnings for the first nine months of 2010 were
$9.64 billion, up $4.06 billion from the same period
in 2009. Higher prices for crude oil and natural gas increased
earnings by $3.46 billion, and an increase in net
oil-equivalent production in the 2010 period benefited income by
about $690 million. A favorable change in tax items of
about $600 million was essentially offset by higher
operating and depreciation expenses. The 2009 period included
gains of about $400 million on asset sales and tax items
related to the Gorgon project in Australia. Foreign currency
effects decreased earnings by $240 million in the 2010
period, compared with a reduction of $522 million a year
earlier, primarily due to unrealized losses on balance sheet
translation.
The average realization per barrel of crude oil and natural gas
liquids in the third quarter 2010 and nine-month period was
about $70, compared with $62 and $52 in the corresponding 2009
periods. The average natural gas realization in the 2010 third
quarter was $4.73 per thousand cubic feet, up from $3.92 in the
third quarter last year. Between the nine-month periods, the
average natural gas realization increased to $4.58 from $3.95.
Net oil-equivalent production was about 2.05 million
barrels per day in the third quarter 2010, up
89,000 barrels per day from the year-ago period. The
increase included 104,000 barrels per day mainly associated
with higher production in Thailand and Brazil and the absence of
effects of 2009 civil unrest in Nigeria. Partially offsetting
this increase were the impacts of planned turnarounds and higher
prices on cost-recovery volumes and other contractual provisions.
Net oil-equivalent production for the nine-months of 2010 was
2.04 million barrels per day, up 71,000 barrels per
day from the 2009 period. The increase included
94,000 barrels per day associated with the
start-up
and
ramp-up
of
several major capital projects — the expansion at
Tengiz in Kazakhstan, Frade in Brazil, Agbami in Nigeria, and
Tombua-Landana
and Mafumeira Norte in Angola. Normal field declines and the
impact of higher prices on cost-recovery volumes and other
contractual provisions decreased net production from last
year’s comparative period.
30
Table of Contents
The net liquids component of oil-equivalent production was
1.42 million barrels per day in the third quarter 2010 and
the nine-month period, an increase of 3 percent for both
respective periods. Net natural gas production of
3.75 billion cubic feet per day in the third quarter 2010
and 3.72 billion cubic feet per day in the first nine
months of 2010 increased 8 percent and 4 percent from
the comparative 2009 periods.
Downstream
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
U.S. Downstream Earnings
|
$349 | $127 | $864 | $212 | ||||||||||||
U.S. downstream earned $349 million in the third
quarter 2010, compared with $127 million a year earlier.
Improved margins on refined products increased earnings by about
$120 million. Higher earnings from chemicals
operations — largely from improved margins at the
50 percent-owned Chevron Phillips Chemical Company LLC
(CPChem) — also increased earnings by $30 million.
Earnings for the first nine months of 2010 were
$864 million, compared with $212 million in the same
period of 2009. Earnings from chemicals operations increased
about $240 million, primarily from higher margins at
CPChem. Improved margins on refined products also increased
earnings by about $240 million in the 2010 period. Lower
operating expenses and favorable
mark-to-market
effects on derivative instruments each benefited earnings by
about $70 million over the 2009 period.
Refinery crude-input of 880,000 barrels per day in the
third quarter 2010 was largely unchanged from the year-ago
period. Inputs of 895,000 barrels per day for the nine
months of 2010 decreased about 2 percent from the
corresponding 2009 period.
Refined product sales of 1.34 million barrels per day for
the quarterly period and 1.37 million barrels per day for
the nine-month period of 2010 declined 5 percent and
4 percent, respectively, from the corresponding periods of
2009. The declines were mainly due to lower gasoline and jet
fuel sales for both periods. Branded gasoline sales decreased to
575,000 and 587,000 barrels per day for the third quarter
and nine months in 2010, representing approximately 8 and
6 percent declines from the corresponding 2009 periods,
primarily due to previously announced exits from selected East
Coast retail markets.
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
International Downstream Earnings*
|
$ 216 | $135 | $872 | $ 934 | ||||||||||||
|
|
||||||||||||||||
|
* Includes foreign currency effects
|
$(118 | ) | $ (89 | ) | $ (83 | ) | $(175 | ) | ||||||||
International downstream earned $216 million in the third
quarter 2010, compared with $135 million a year earlier.
The increase was mainly due to improved refined product margins
of about $220 million, partially offset by unfavorable
mark-to-market
effects on derivative instruments of about $130 million.
Foreign currency effects decreased earnings by $118 million
in the 2010 quarter, compared with a reduction of
$89 million a year earlier.
Earnings for the first nine months of 2010 were
$872 million, down $62 million from the corresponding
2009 period. The decline was mainly due to the absence of 2009
gains on asset sales of about $540 million and higher
charges of $110 million, primarily related to employee
reductions. Higher margins on the sale of gasoline and other
refined products increased earnings by about $340 million,
and a favorable swing in
mark-to-market
effects on derivative instruments benefited earnings by about
$320 million. Foreign currency effects reduced earnings by
$83 million in 2010, compared with a reduction of
$175 million a year earlier.
The company’s share of crude oil inputs to refineries was
1,027,000 barrels per day in the 2010 third quarter, up
42,000 from the year-ago period. For the nine months of 2010,
crude oil inputs were 991,000 barrels per day, up
31
Table of Contents
11,000 from the year-ago period. The increase for both
comparative periods was attributable mainly to increased demand
in Asia.
Refined product sales volumes of 1.76 million barrels per
day in the 2010 third quarter were 3 percent lower than a
year earlier, mainly due to lower sales of gas oil and gasoline.
Total refined product sales of about 1.75 million barrels
per day for the first nine months of 2010 were about
6 percent lower than in the corresponding periods of 2009,
mainly due to asset sales in certain countries in Africa and
Latin America.
All
Other
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Net Charges*
|
$(361 | ) | $(167 | ) | $(837 | ) | $(504 | ) | ||||||||
|
|
||||||||||||||||
|
* Includes foreign currency effects
|
$ (4 | ) | $ 8 | $ (1 | ) | $ 20 | ||||||||||
All Other consists of mining operations, power generation
businesses, worldwide cash management and debt financing
activities, corporate administrative functions, insurance
operations, real estate activities, alternative fuels and
technology companies.
Net charges in the third quarter 2010 were $361 million,
compared with $167 million in the year-ago period. The
change between periods was mainly due to higher corporate tax
items. Foreign currency effects increased net charges by
$4 million in the 2010 quarter, compared with an
$8 million reduction in net charges last year. For the nine
months of 2010, net charges were $837 million, compared
with $504 million a year earlier. Net charges for corporate
tax items and employee compensation and benefits were higher in
the 2010 nine-month period.
Consolidated
Statement of Income
Explanations of variations between periods for certain income
statement categories are provided below:
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Sales and other operating revenues
|
$48,554 | $45,180 | $146,346 | $119,814 | ||||||||||||
Sales and other operating revenues for the quarterly and
nine-month periods increased $3 billion and
$27 billion, respectively, mainly due to higher prices for
crude oil, natural gas and refined products.
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Income from equity affiliates
|
$1,242 | $1,072 | $4,127 | $2,418 | ||||||||||||
Income from equity affiliates increased between the quarterly
and nine-month periods due mainly to higher upstream-related
earnings from Tengizchevroil in Kazakhstan and Petropiar in
Venezuela, principally related to higher prices for crude oil
and increased crude oil production. Downstream-related earnings
were also higher between the comparative periods primarily due
to higher earnings from Chevron Phillips Chemical Company LLC,
as a result of higher margins on sales of commodity chemicals.
Improved margins on refined products and a favorable swing in
foreign currency effects at GS Caltex in South Korea also
contributed to the increase of the downstream-related earnings
in the 2010 nine-month period.
32
Table of Contents
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Other income
|
$ (78 | ) | $ 373 | $ 428 | $ 728 | |||||||||||
Other income for the quarterly period in 2010 decreased mainly
due to lower gains on asset sales and an unfavorable change in
foreign currency effects. The decrease for the nine-month period
was primarily the result of lower gains on asset sales,
partially offset by lower foreign currency losses.
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Purchased crude oil and products
|
$28,610 | $26,969 | $86,358 | $71,047 | ||||||||||||
Purchases increased $2 billion and $15 billion in the
quarterly and nine-month periods mainly due to higher prices for
crude oil, natural gas and refined products.
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Operating, selling, general and administrative expenses
|
$5,846 | $5,580 | $17,204 | $16,155 | ||||||||||||
Operating, selling, general and administrative expenses
increased $266 million between quarters and
$1.05 billion between the nine-month periods. The increase
in the quarterly period in 2010 was mainly due to higher fuel
expenses of $220 million. Higher expenses for the 2010
nine-month period include $800 million associated with
employee compensation and benefits, tanker charter rates, and
fuel. In addition, charges of $244 million related to
employee reductions recorded in the first quarter are included
in the 2010 nine-month period.
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Exploration expenses
|
$ 420 | $ 242 | $ 812 | $1,061 | ||||||||||||
Exploration expenses for the quarterly period 2010 increased due
to higher amounts for well write-offs. The decline in
exploration expenses between nine-month periods was due to lower
amounts for well write-offs and geological and geophysical costs.
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Depreciation, depletion and amortization
|
$3,401 | $2,988 | $9,624 | $8,954 | ||||||||||||
The increase in expenses for the third quarter and nine-month
periods was mainly associated with higher depreciation rates and
higher production for certain oil and gas producing fields.
Partially offsetting these effects were lower upstream
impairments in both comparative periods.
33
Table of Contents
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Taxes other than on income
|
$4,559 | $4,644 | $13,568 | $13,008 | ||||||||||||
Taxes other than on income for the quarterly period 2010
decreased mainly due to lower import duties in the
company’s U.K. downstream operations. The increase for the
nine-month period was primarily due to higher import duties in
the company’s U.K. downstream operations and higher excise
taxes in Canada.
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
| (Millions of dollars) | ||||||||||||||||
|
Income tax expense
|
$3,081 | $2,342 | $9,473 | $5,246 | ||||||||||||
Effective income tax rates for the 2010 and 2009 third quarters
were 45 percent and 38 percent, respectively. For the
year-to-date
periods, the effective tax rates were 41 percent for both
periods. The increase in the effective tax rate in the quarterly
comparison was primarily due to the effect of one-time tax
benefits in 2009 that were significantly higher than those
generated in the comparable 2010 period. Additionally, foreign
currency translation losses were greater in the 2010 quarter,
resulting in a larger reduction in Income Before Income Tax
Expense, with no corresponding impact on Income Tax Expense.
Partially offsetting these items was the increased utilization
of tax credits resulting from higher profits in certain foreign
tax jurisdictions in the 2010 period. For the comparative
nine-month periods, greater one-time tax benefits were generated
in 2009 than in 2010. This effect was essentially offset by
increased tax credit utilization in foreign tax jurisdictions in
2010 and by foreign currency translation impacts.
34
Table of Contents
Selected
Operating Data
The following table presents a comparison of selected operating
data:
Selected
Operating Data(1)(2)
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
|
U.S. Upstream
|
||||||||||||||||
|
Net crude oil and natural gas liquids production (MBPD)
|
482 | 509 | 492 | 472 | ||||||||||||
|
Net natural gas production (MMCFPD)(3)
|
1,255 | 1,420 | 1,317 | 1,398 | ||||||||||||
|
Net oil-equivalent production (MBOEPD)
|
692 | 745 | 711 | 705 | ||||||||||||
|
Sales of natural gas (MMCFPD)
|
6,091 | 5,832 | 5,956 | 5,974 | ||||||||||||
|
Sales of natural gas liquids (MBPD)(4)
|
22 | 18 | 23 | 16 | ||||||||||||
|
Revenue from net production
|
||||||||||||||||
|
Liquids ($/Bbl)
|
$68.85 | $60.20 | $70.03 | $49.53 | ||||||||||||
|
Natural gas ($/MCF)
|
$ 4.06 | $ 3.28 | $ 4.47 | $ 3.56 | ||||||||||||
|
International Upstream
|
||||||||||||||||
|
Net crude oil and natural gas liquids production (MBPD)(4)(5)
|
1,422 | 1,377 | 1,423 | 1,378 | ||||||||||||
|
Net natural gas production (MMCFPD)(3)
|
3,748 | 3,475 | 3,723 | 3,570 | ||||||||||||
|
Net oil-equivalent production (MBOEPD)
|
2,046 | 1,957 | 2,044 | 1,973 | ||||||||||||
|
Sales of natural gas (MMCFPD)
|
4,597 | 4,035 | 4,486 | 4,084 | ||||||||||||
|
Sales of natural gas liquids (MBPD)(4)
|
28 | 21 | 28 | 21 | ||||||||||||
|
Revenue from liftings
|
||||||||||||||||
|
Liquids ($/Bbl)
|
$69.67 | $61.90 | $70.39 | $51.50 | ||||||||||||
|
Natural gas ($/MCF)
|
$ 4.73 | $ 3.92 | $ 4.58 | $ 3.95 | ||||||||||||
|
U.S. and International Upstream
|
||||||||||||||||
|
Total net oil-equivalent production (MBOEPD)(3)
|
2,738 | 2,702 | 2,755 | 2,678 | ||||||||||||
|
U.S. Downstream
|
||||||||||||||||
|
Gasoline sales (MBPD)(6)
|
696 | 737 | 716 | 725 | ||||||||||||
|
Other refined product sales (MBPD)
|
647 | 679 | 651 | 695 | ||||||||||||
|
Total refined product sales
|
1,343 | 1,416 | 1,367 | 1,420 | ||||||||||||
|
Sales of natural gas liquids (MBPD)(4)
|
135 | 143 | 139 | 142 | ||||||||||||
|
Refinery input (MBPD)
|
880 | 879 | 895 | 913 | ||||||||||||
|
International Downstream
|
||||||||||||||||
|
Gasoline sales (MBPD)(6)
|
410 | 435 | 412 | 458 | ||||||||||||
|
Other refined product sales (MBPD)
|
781 | 868 | 790 | 905 | ||||||||||||
|
Share of affiliate sales (MBPD)
|
568 | 519 | 551 | 504 | ||||||||||||
|
Total refined product sales
|
1,759 | 1,822 | 1,753 | 1,867 | ||||||||||||
|
Sales of natural gas liquids (MBPD)(4)
|
76 | 83 | 75 | 89 | ||||||||||||
|
Refinery input (MBPD)
|
1,027 | 985 | 991 | 980 | ||||||||||||
|
|
||||||||||||||||
|
(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
|
59 | 56 | 63 | 57 | ||||||||||||
|
International
|
500 | 455 | 474 | 467 | ||||||||||||
|
(4) 2009 conformed to 2010 presentation
|
||||||||||||||||
|
(5) Includes: Canada — synthetic oil
|
27 | 27 | 22 | 26 | ||||||||||||
|
Venezuela affiliate — synthetic oil
|
28 | 24 | 29 | 26 | ||||||||||||
|
(6) Includes branded and unbranded gasoline.
|
||||||||||||||||
35
Table of Contents
Liquidity
and Capital Resources
Cash, cash equivalents, time deposits and marketable
securities
totaled approximately $14.5 billion at
September 30, 2010, up $5.7 billion from year-end
2009. Cash provided by operating activities in the first nine
months of 2010 was $23.1 billion, compared with
$12.4 billion in the year-ago period. Operating cash flows
generated funds in excess of the requirements for the
company’s $14.6 billion capital and exploratory
program and $4.2 billion of dividend payments to common
shareholders during the first nine months of 2010.
Dividends
The company paid dividends of $4.2 billion
to common stockholders during the first nine months of 2010. In
October 2010, the company declared a quarterly dividend of 72
cents per common share payable in December 2010.
Debt and Capital Lease Obligations
Chevron’s total
debt and capital lease obligations were $10.6 billion and
$10.5 billion at September 30, 2010 and
December 31, 2009, respectively.
The $100 million increase in total debt and capital lease
obligations during the first nine months of 2010 included a
$350 million issuance of a tax-exempt Gulf Opportunity Zone
bond, partially offset by a decrease in short-term obligations.
The company’s 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 $4.7 billion and $4.6 billion at
September 30, 2010 and December 31, 2009,
respectively. Of this amount, $4.5 billion was reclassified
to long-term at the end of September 30, 2010. At
December 31, 2009, $4.2 billion was reclassified to
long-term. At September 30, 2010, settlement of these
obligations was not expected to require the use of working
capital within one year, as the company had the intent and the
ability, as evidenced by committed credit facilities, to
refinance them on a long-term basis.
At September 30, 2010, 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 company’s practice has been to continually replace
expiring commitments with new commitments on substantially the
same terms, maintaining levels management believes appropriate.
Any borrowings under the facilities would be unsecured
indebtedness at interest rates based on London Interbank Offered
Rate or an average of base lending rates published by specified
banks and on terms reflecting the company’s strong credit
rating. No borrowings were outstanding under these facilities at
September 30, 2010. 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
company’s debt, and the company’s 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, Texaco Capital Inc. and Union Oil Company of
California. All of these securities are the obligations of, or
guaranteed by, Chevron Corporation and are rated AA by Standard
and Poor’s Corporation and Aa1 by Moody’s Investors
Service. The company’s U.S. commercial paper is rated
A-1+
by
Standard and Poor’s and
P-1
by
Moody’s. All of these ratings denote high-quality,
investment-grade securities.
The company’s future debt level is dependent primarily on
results of operations, the capital-spending program and cash
that may be generated from asset dispositions. 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 company’s high-quality debt ratings.
Common Stock Repurchase Program
In July 2010, the company
terminated the $15 billion share repurchase program
initiated in September 2007. No share repurchases occurred in
2010 prior to the termination of this program. From the
inception of the program, the company acquired 119 million
shares at a cost of $10.1 billion. In its place, the Board
of Directors approved a new, ongoing share repurchase program
with no set term or monetary limits. Under the new program, the
company will acquire its common shares at prevailing prices, as
permitted by securities laws and other legal requirements and
subject to market conditions and other factors. No shares were
36
Table of Contents
purchased under the new program through September 30, 2010.
In October 2010, the company announced that it would begin
purchases of its common stock in the fourth quarter 2010 under
the ongoing share repurchase program. The company expects a
repurchase rate between $500 million and $1 billion
per quarter.
Noncontrolling Interests
The company reported
noncontrolling interests of $722 million and
$647 million at September 30, 2010 and
December 31, 2009, respectively. Distributions to
noncontrolling interests totaled $56 million during the
first nine months of 2010.
Current Ratio
— current assets divided by
current liabilities, which indicates the company’s ability
to repay its short-term liabilities with short-term assets. The
current ratio was 1.7 at September 30, 2010, and 1.4 at
December 31, 2009. The current ratio is adversely affected
by the fact that Chevron’s inventories are valued on a
Last-In,
First-Out basis. At September 30, 2010, 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 company’s leverage. This ratio was
9.4 percent at September 30, 2010, and
10.3 percent at year-end 2009.
Pension Obligations
At the end of 2009, the company
estimated it would contribute $900 million to employee
pension plans during 2010 (composed of $600 million for the
U.S. plans and $300 million for the international
plans). Through September 30, 2010, a total of
$895 million was contributed (including $790 million
to the U.S. plans). Total contributions for the full year
are currently estimated to be $1.5 billion
($1.2 billion for the U.S. plans and $300 million
for the international plans). Actual contribution amounts are
dependent upon investment returns, changes in pension
obligations, regulatory environments and other economic factors.
Additional funding may ultimately be required if investment
returns are insufficient to offset increases in plan obligations.
Capital and Exploratory Expenditures
Total expenditures,
including the company’s share of spending by affiliates,
were $15.5 billion in the first nine months of 2010,
compared with $16.0 billion in the corresponding 2009
period. The amounts included the company’s share of
affiliates’ expenditures of about $900 million for
both 2010 and 2009 periods. Outlays in the 2009 period included
$2 billion for the extension of an upstream concession.
Expenditures for upstream projects in the first nine months of
2010 were about $13.8 billion, representing 89 percent
of the companywide total.
Capital
and Exploratory Expenditures by Major Operating Area
|
Three Months Ended
|
Nine Months Ended
|
|||||||||||||||
| September 30 | September 30 | |||||||||||||||
| 2010 | 2009 | 2010 | 2009 | |||||||||||||
|
United States
|
||||||||||||||||
|
Upstream
|
$ | 736 | $ | 669 | $ | 2,268 | $ | 2,496 | ||||||||
|
Downstream
|
313 | 496 | 916 | 1,478 | ||||||||||||
|
All Other
|
80 | 100 | 182 | 256 | ||||||||||||
|
Total United States
|
1,129 | 1,265 | 3,366 | 4,230 | ||||||||||||
|
International
|
||||||||||||||||
|
Upstream
|
4,716 | 3,031 | 11,488 | 10,976 | ||||||||||||
|
Downstream
|
264 | 300 | 676 | 804 | ||||||||||||
|
All Other
|
3 | — | 7 | 1 | ||||||||||||
|
Total International
|
4,983 | 3,331 | 12,171 | 11,781 | ||||||||||||
|
Worldwide
|
$ | 6,112 | $ | 4,596 | $ | 15,537 | $ | 16,011 | ||||||||
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 19 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
37
Table of Contents
company to correct or ameliorate the alleged effects on the
environment of prior release of MTBE by the company or other
parties. Additional lawsuits and claims related to the use of
MTBE, including personal-injury claims, may be filed in the
future. The company’s ultimate exposure related to pending
lawsuits and claims is not determinable, but could be material
to net income in any one period. The company no longer uses MTBE
in the manufacture of gasoline in the United States.
Ecuador
Chevron is a defendant in a civil lawsuit before
the Superior Court of Nueva Loja in Lago Agrio, Ecuador, brought
in May 2003 by plaintiffs who claim to be representatives of
certain residents of an area where an oil production consortium
formerly had operations. The lawsuit alleges damage to the
environment from the oil exploration and production operations
and seeks unspecified damages to fund environmental remediation
and restoration of the alleged environmental harm, plus a health
monitoring program. Until 1992, Texaco Petroleum Company
(Texpet), a subsidiary of Texaco Inc., was a minority member of
this consortium with Petroecuador, the Ecuadorian state-owned
oil company, as the majority partner; since 1990, the operations
have been conducted solely by Petroecuador. At the conclusion of
the consortium and following an independent third-party
environmental audit of the concession area, Texpet entered into
a formal agreement with the Republic of Ecuador and Petroecuador
for Texpet to remediate specific sites assigned by the
government in proportion to Texpet’s ownership share of the
consortium. Pursuant to that agreement, Texpet conducted a
three-year remediation program at a cost of $40 million.
After certifying that the sites were properly remediated, the
government granted Texpet and all related corporate entities a
full release from any and all environmental liability arising
from the consortium operations.
Based on the history described above, Chevron believes that this
lawsuit lacks legal or factual merit. As to matters of law, the
company believes first, that the court lacks jurisdiction over
Chevron; second, that the law under which plaintiffs bring the
action, enacted in 1999, cannot be applied retroactively; third,
that the claims are barred by the statute of limitations in
Ecuador; and, fourth, that the lawsuit is also barred by the
releases from liability previously given to Texpet by the
Republic of Ecuador and Petroecuador and by the pertinent
provincial and municipal governments. With regard to the facts,
the company believes that the evidence confirms that
Texpet’s remediation was properly conducted and that the
remaining environmental damage reflects Petroecuador’s
failure to timely fulfill its legal obligations and
Petroecuador’s further conduct since assuming full control
over the operations.
In 2008, a mining engineer appointed by the court to identify
and determine the cause of environmental damage, and to specify
steps needed to remediate it, issued a report recommending that
the court assess $18.9 billion, which would, according to
the engineer, provide financial compensation for purported
damages, including wrongful death claims, and pay for, among
other items, environmental remediation, health care systems and
additional infrastructure for Petroecuador. The engineer’s
report also asserted that an additional $8.4 billion could
be assessed against Chevron for unjust enrichment. In 2009,
following the disclosure by Chevron of evidence that the judge
participated in meetings in which businesspeople and individuals
holding themselves out as government officials discussed the
case and its likely outcome, the judge presiding over the case
was recused. In 2010, Chevron moved to strike the mining
engineer’s report and to dismiss the case based on evidence
obtained through discovery in the United States indicating that
the report was prepared by consultants for the plaintiffs before
being presented as the mining engineer’s independent and
impartial work and showing further evidence of misconduct. In
August 2010, the judge issued an order stating that he was not
bound by the mining engineer’s report and requiring the
parties to provide their positions on damages within
45 days. Chevron subsequently petitioned for recusal of the
judge, claiming that he had disregarded evidence of fraud and
misconduct and that he had failed to rule on a number of motions
within the statutory time requirement.
In September 2010, Chevron submitted its position on damages,
asserting that no amount should be assessed against it. The
plaintiffs’ submission, which relied in part on the mining
engineer’s report, took the position that damages are
between approximately $16 billion and $76 billion and
that unjust enrichment should be assessed in an amount between
approximately $5 billion and $38 billion. The next
day, the judge issued an order closing the evidentiary phase of
the case and notifying the parties that he had requested the
case file so that he could prepare a judgment. Chevron
petitioned to have that order declared a nullity in light of
Chevron’s prior recusal petition, and because procedural
and evidentiary matters remain unresolved. In October 2010,
Chevron’s motion to recuse the judge was granted. A new
judge has taken charge of the case, and that judge has revoked
the prior judge’s order closing the evidentiary phase of
the case.
38
Table of Contents
Chevron cannot predict the timing or content of future
developments in the Lago Agrio litigation, and a judgment could
be entered at any time. Chevron will continue a vigorous defense
of any attempted imposition of liability. In the event of an
adverse trial court judgment, Chevron would expect to pursue its
appeals in Ecuador. Because Chevron has no substantial assets in
Ecuador, Chevron would expect enforcement actions following any
adverse judgment to be brought in other jurisdictions. Chevron
would expect to contest any such actions. The ultimate outcome,
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 2008 engineer’s report and the
September 2010 plaintiffs’ submission, management does not
believe those 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, generally the
company would be required to perform should the affiliated
company or third party fail to fulfill its obligations under the
arrangements. In some cases, the guarantee arrangements may have
recourse provisions that would enable the company to recover any
payments made under the terms of the guarantees from assets
provided as collateral.
Off-Balance-Sheet Obligations
The company and its
subsidiaries have certain other contingent liabilities relating
to long-term unconditional purchase obligations and commitments,
including throughput and
take-or-pay
agreements, some of which relate to suppliers’ financing
arrangements. The agreements typically provide goods and
services, such as pipeline and storage capacity, drilling rigs,
utilities, and petroleum products, to be used or sold in the
ordinary course of the company’s business.
Indemnifications
The company provided certain indemnities
of contingent liabilities of Equilon and Motiva to Shell and
Saudi Refining, Inc., in connection with the February 2002 sale
of the company’s interests in those investments. The
company would be required to perform if the indemnified
liabilities become actual losses. Were that to occur, the
company could be required to make future payments up to
$300 million. Through September 2010, the company paid
$48 million under these indemnities and continues to be
obligated for possible additional indemnification payments in
the future.
The company has also provided indemnities relating to contingent
environmental liabilities related to assets originally
contributed by Texaco to the Equilon and Motiva joint ventures
and environmental conditions that existed prior to the formation
of Equilon and Motiva or that occurred during the period of
Texaco’s ownership interest in the joint ventures. In
general, the environmental conditions or events that are subject
to these indemnities must have arisen prior to December 2001.
Claims had to be asserted by February 2009 for Equilon
indemnities and must be asserted no later than February 2012 for
Motiva indemnities. Under the terms of these indemnities, there
is no maximum limit on the amount of potential future payments.
In February 2009, Shell delivered a letter to the company
purporting to preserve unmatured claims for certain Equilon
indemnities. The letter itself provides no estimate of the
ultimate claim amount. Management does not believe this letter
or any other information provides a basis to estimate the
amount, if any, of a range of loss or potential range of loss
with respect to either the Equilon or the Motiva indemnities.
The company posts no assets as collateral and has made no
payments under the indemnities.
The amounts payable for the indemnities described 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.
39
Table of Contents
Although the company has provided for known obligations under
this indemnity that are probable and reasonably estimable, the
amount of additional future costs may be material to results of
operations in the period in which they are recognized. The
company does not expect these costs will have a material effect
on its consolidated financial position or liquidity.
Environmental
The company is subject to loss
contingencies pursuant to laws, regulations, private claims and
legal proceedings related to environmental matters that are
subject to legal settlements or that in the future may require
the company to take action to correct or ameliorate the effects
on the environment of prior release of chemicals or petroleum
substances, including MTBE, by the company or other parties.
Such contingencies may exist for various sites, including, but
not limited to, federal Superfund sites and analogous sites
under state laws, refineries, crude oil fields, service
stations, terminals, land development areas, and mining
operations, whether operating, closed or divested. These future
costs are not fully determinable due to such factors as the
unknown magnitude of possible contamination, the unknown timing
and extent of the corrective actions that may be required, the
determination of the company’s liability in proportion to
other responsible parties, and the extent to which such costs
are recoverable from third parties.
Although the company has provided for known environmental
obligations that are probable and reasonably estimable, the
amount of additional future costs may be material to results of
operations in the period in which they are recognized. The
company does not expect these costs will have a material effect
on its consolidated financial position or liquidity. Also, the
company does not believe its obligations to make such
expenditures have had, or will have, any significant impact on
the company’s competitive position relative to other
U.S. or international petroleum or chemical companies.
Financial Instruments
The company believes it has no
material market or credit risks to its operations, financial
position or liquidity as a result of its commodities and other
derivative activities.
Equity Redetermination
For crude oil and natural gas
producing operations, ownership agreements may provide for
periodic reassessments of equity interests in estimated crude
oil and natural gas reserves. These activities, individually or
together, may result in gains or losses that could be material
to earnings in any given period. One such equity redetermination
process has been under way since 1996 for Chevron’s
interests in four producing zones at the Naval Petroleum Reserve
at Elk Hills, California, for the time when the remaining
interests in these zones were owned by the U.S. Department
of Energy. A wide range remains for a possible net settlement
amount for the four zones. For this range of settlement, Chevron
estimates its maximum possible net before-tax liability at
approximately $200 million, and the possible maximum net
amount that could be owed to Chevron is estimated at about
$150 million. The timing of the settlement and the exact
amount within this range of estimates are uncertain.
Income Taxes
Tax positions for Chevron and its
subsidiaries and affiliates are subject to income tax audits by
many tax jurisdictions throughout the world. For the
company’s major tax jurisdictions, examinations of tax
returns for certain prior tax years had not been completed as of
September 30, 2010. For these jurisdictions, the latest
years for which income tax examinations had been finalized were
as follows: United States — 2005, Nigeria —
1994, Angola — 2001 and Saudi Arabia — 2003.
Settlement of open tax years, as well as tax issues in other
countries where the company conducts its businesses, is not
expected to have a material effect on the consolidated financial
position or liquidity of the company and, in the opinion of
management, adequate provision has been made for income and
franchise taxes for all years under examination or subject to
future examination.
Other Contingencies
On April 26, 2010, a California
appeals court issued a ruling related to the adequacy of an
Environmental Impact Report (EIR) supporting the issuance of
certain permits by the city of Richmond, California, to replace
and upgrade certain facilities at Chevron’s refinery in
Richmond. The parties to the case have stipulated that entry of
final judgment by the trial court be postponed pending on-going
settlement discussions. The company continues to evaluate its
options going forward, which may include settlement, requesting
the city to revise the EIR to address the issues identified by
the Court of Appeal or other actions. Management believes the
outcomes associated with the potential options for the project
are uncertain. Due to the uncertainty of the company’s
future course of action, or potential outcomes of any action or
combination of actions, management does not believe an
40
Table of Contents
estimate of the financial effects, if any, of the ruling can be
made at this time. However, the company’s ultimate exposure
may be significant to net income in any one future period.
Chevron receives claims from and submits claims to customers;
trading partners; U.S. federal, state and local regulatory
bodies; governments; contractors; insurers; and suppliers. The
amounts of these claims, individually and in the aggregate, may
be significant and take lengthy periods to resolve.
The company and its affiliates also continue to review and
analyze their operations and may close, abandon, sell, exchange,
acquire or restructure assets to achieve operational or
strategic benefits and to improve competitiveness and
profitability. These activities, individually or together, may
result in gains or losses in future periods.
New
Accounting Standards
Transfers and Servicing (ASC 860), Accounting for Transfers
of Financial Assets (ASU
2009-16)
The FASB issued ASU
2009-16
in
December 2009. This standard became effective for the company on
January 1, 2010. ASU
2009-16
changes how companies account for transfers of financial assets
and eliminates the concept of qualifying special-purpose
entities. Adoption of the guidance did not have an effect on the
company’s results of operations, financial position or
liquidity.
Consolidation (ASC 810), Improvements to Financial Reporting
by Enterprises Involved With Variable Interest Entities (ASU
2009-17)
The FASB issued ASU
2009-17
in
December 2009. This standard became effective for the company on
January 1, 2010. ASU
2009-17
requires the enterprise to qualitatively assess if it is the
primary beneficiary of a variable-interest entity (VIE), and, if
so, the VIE must be consolidated. Adoption of the standard did
not have an impact on the company’s results of operations,
financial position or liquidity.
Receivables (ASC 310), Disclosures about the Credit Quality
of Financing Receivables and the Allowance for Credit Losses
(ASU
2010-20)
In July 2010, the FASB issued ASU
2010-20,
which becomes effective with the company’s reporting at
December 31, 2010. This standard amends and expands
disclosure requirements about the credit quality of financing
receivables and the related allowance for credit losses. As a
result of these amendments, companies are required to
disaggregate, by portfolio segment or class of financing
receivable, certain existing disclosures and provide certain new
disclosures about financing receivables and related allowance
for credit losses. The company does not anticipate changes to
its existing disclosures when the standard becomes effective.
| Item 3. | Quantitative and Qualitative Disclosures About Market Risk |
Information about market risks for the three months ended
September 30, 2010, does not differ materially from that
discussed under Item 7A of Chevron’s 2009 Annual
Report on
Form 10-K.
| Item 4. | Controls and Procedures |
(a) Evaluation of disclosure controls and procedures
The company’s management has evaluated, with the
participation of the Chief Executive Officer and Chief Financial
Officer, the effectiveness of the company’s disclosure
controls and procedures (as defined in
Rule 13a-15(e)
and
15d-15(e)
under the Securities Exchange Act of 1934) as of the end of
the period covered by this report. Based on this evaluation, the
Chief Executive Officer and Chief Financial Officer concluded
that the company’s disclosure controls and procedures were
effective as of September 30, 2010.
(b) Changes in internal control over financial reporting
During the quarter ended September 30, 2010, there were no
changes in the company’s internal control over financial
reporting that have materially affected, or are reasonably
likely to materially affect, the company’s internal control
over financial reporting.
41
Table of Contents
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 Texpet’s ownership share of the
consortium. Pursuant to that agreement, Texpet conducted a
three-year remediation program at a cost of $40 million.
After certifying that the sites were properly remediated, the
government granted Texpet and all related corporate entities a
full release from any and all environmental liability arising
from the consortium operations.
Based on the history described above, Chevron believes that this
lawsuit lacks legal or factual merit. As to matters of law, the
company believes first, that the court lacks jurisdiction over
Chevron; second, that the law under which plaintiffs bring the
action, enacted in 1999, cannot be applied retroactively; third,
that the claims are barred by the statute of limitations in
Ecuador; and, fourth, that the lawsuit is also barred by the
releases from liability previously given to Texpet by the
Republic of Ecuador and Petroecuador and by the pertinent
provincial and municipal governments. With regard to the facts,
the company believes that the evidence confirms that
Texpet’s remediation was properly conducted and that the
remaining environmental damage reflects Petroecuador’s
failure to timely fulfill its legal obligations and
Petroecuador’s further conduct since assuming full control
over the operations.
In 2008, a mining engineer appointed by the court to identify
and determine the cause of environmental damage, and to specify
steps needed to remediate it, issued a report recommending that
the court assess $18.9 billion, which would, according to
the engineer, provide financial compensation for purported
damages, including wrongful death claims, and pay for, among
other items, environmental remediation, health care systems and
additional infrastructure for Petroecuador. The engineer’s
report also asserted that an additional $8.4 billion could
be assessed against Chevron for unjust enrichment. In 2009,
following the disclosure by Chevron of evidence that the judge
participated in meetings in which businesspeople and individuals
holding themselves out as government officials discussed the
case and its likely outcome, the judge presiding over the case
was recused. In 2010, Chevron moved to strike the mining
engineer’s report and to dismiss the case based on evidence
obtained through discovery in the United States indicating that
the report was prepared by consultants for the plaintiffs before
being presented as the mining engineer’s independent and
impartial work and showing further evidence of misconduct. In
August 2010, the judge issued an order stating that he was not
bound by the mining engineer’s report and requiring the
parties to provide their positions on damages within
45 days. Chevron subsequently petitioned for recusal of the
judge, claiming that he had disregarded evidence of fraud and
misconduct and that he had failed to rule on a number of motions
within the statutory time requirement.
In September 2010, Chevron submitted its position on damages,
asserting that no amount should be assessed against it. The
plaintiffs’ submission, which relied in part on the mining
engineer’s report, took the position that damages are
between approximately $16 billion and $76 billion and
that unjust enrichment should be assessed in an amount between
approximately $5 billion and $38 billion. The next
day, the judge issued an order closing the evidentiary phase of
the case and notifying the parties that he had requested the
case file so that he could prepare a judgment. Chevron
petitioned to have that order declared a nullity in light of
Chevron’s prior recusal petition, and because procedural
and evidentiary matters remain unresolved. In October 2010,
Chevron’s motion to recuse the judge was granted. A new
judge has taken charge of the case, and that judge has revoked
the prior judge’s order closing the evidentiary phase of
the case.
42
Table of Contents
Chevron cannot predict the timing or content of future
developments in the Lago Agrio litigation, and a judgment could
be entered at any time. Chevron will continue a vigorous defense
of any attempted imposition of liability. In the event of an
adverse trial court judgment, Chevron would expect to pursue its
appeals in Ecuador. Because Chevron has no substantial assets in
Ecuador, Chevron would expect enforcement actions following any
adverse judgment to be brought in other jurisdictions. Chevron
would expect to contest any such actions. The ultimate outcome,
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 2008 engineer’s report and the
September 2010 plaintiffs’ submission, management does not
believe those 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 July 14, 2009, the
California Air Resources Board (CARB) issued a notice of
violation against Chevron Products Company for alleged
violations of CARB’s regulations governing the
certification of gasoline that occurred during storage at a
third-party facility and which had been self-reported by the
company on discovery. The company has determined that resolution
of this matter may result in the payment of a civil penalty
exceeding $100,000.
As previously reported in the company’s quarterly report
for the period ended March 31, 2010, Chevron agreed to pay
the New Mexico Environmental Department a $182,000 civil penalty
and undertake certain corrective measures with respect to
alleged violations of the agency’s air pollution
regulations identified in a June 12, 2009 notice of
violation. The alleged violations related to the company’s
air permit at the Buckeye
CO
2
plant located southeast of Lovington, New Mexico. The penalty
has been paid, and the matter is closed.
| Item 1A. | Risk Factors |
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 company’s financial results of
operations or financial condition.
Information about risk factors for the three months ended
September 30, 2010, does not differ materially from that
set forth in Part I, Item 1A, of Chevron’s 2009
Annual Report on
Form 10-K.
43
Table of Contents
| Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds |
CHEVRON
CORPORATION
ISSUER
PURCHASES OF EQUITY SECURITIES
|
Maximum
|
||||||||||||||||
|
Total
|
Total Number of
|
Number of Shares
|
||||||||||||||
|
Number of
|
Average
|
Shares Purchased as
|
that May Yet Be
|
|||||||||||||
|
Shares
|
Price Paid
|
Part of Publicly
|
Purchased Under
|
|||||||||||||
| Period | Purchased(1) | per Share | Announced Program | the Program(2) | ||||||||||||
|
July 1-31, 2010
|
3,310 | 67.47 | — | |||||||||||||
|
August 1-31, 2010
|
8,632 | 78.66 | — | |||||||||||||
|
September 1-30, 2010
|
5,832 | 79.61 | — | |||||||||||||
|
Total
|
17,774 | 76.89 | — | |||||||||||||
| (1) | Pertains to common shares repurchased during the three-month period ended September 30, 2010, 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 September 30, 2010. | |
| (2) | In July 2010, the company terminated the $15 billion share repurchase program initiated in September 2007. No share repurchases occurred in 2010 prior to the termination of this program. From the inception of the program, the company acquired 118,996,749 shares at a cost of $10.1 billion. In its place, the Board of Directors approved a new, ongoing share repurchase program with no set term or monetary limits. Under the new program, the company will acquire its common shares at prevailing prices, as permitted by securities laws and other legal requirements and subject to market conditions and other factors. No shares were purchased under the new program through September 30, 2010. |
44
Table of Contents
| Item 5. | Other Information |
Reporting Requirements Regarding Coal or Other Mine Safety
Chevron is an operator of the following coal and molybdenum
mines for which reporting requirements apply under
Section 1503 of the Dodd-Frank Wall Street Reform and
Consumer Protection Act as a result of communications received
from the Mine Safety and Health Administration (MSHA) during the
three months ended September 30, 2010. In evaluating this
information, consideration should be given to factors such as:
(i) the number of citations and orders will vary depending
on the size of the mine, (ii) the number of citations
issued will vary from inspector to inspector and mine to mine,
and (iii) citations and orders can be contested and
appealed, and in that process, are often reduced in severity and
amount, and are sometimes dismissed.
The items in the table below refer to the applicable sections of
the Federal Mine Safety and Health Administration Act of 1977
under which the communication was received.
|
Number of
|
||||||||||||||||||||||||
|
Violations
|
Number of
|
Number of
|
Total
|
|||||||||||||||||||||
|
For Which
|
Citations
|
Number of
|
Imminent
|
Dollar
|
||||||||||||||||||||
|
Significant and
|
Number of
|
and Orders for
|
Flagrant
|
Danger
|
Value of
|
|||||||||||||||||||
|
Substantial
|
Orders
|
Unwarrantable
|
Violations
|
Orders
|
Proposed
|
|||||||||||||||||||
|
Citations Were
|
Received
|
Failure
|
Received
|
Received
|
MSHA
|
|||||||||||||||||||
|
Received Under
|
Under
|
Under
|
Under
|
Under
|
Assessments
|
|||||||||||||||||||
| Mine | Sec. 104 | Sec. 104(b) | Sec. 104(d) | Sec. 110(b)(2) | Sec. 107(a) | (thousands) | ||||||||||||||||||
|
Kemmerer Mine
|
10 | — | — | — | — | $ | 49 | |||||||||||||||||
|
McKinley Mine
|
— | — | — | — | — | — | ||||||||||||||||||
|
North River Mine
|
16 | — | 2 | — | — | $ | 21 | |||||||||||||||||
|
Questa Mine
|
10 | — | — | — | — | $ | 5 | |||||||||||||||||
For the three-month period ended September 30, 2010, there
were no coal or other mines, of which Chevron is an operator,
that received written notice from MSHA of (1) a pattern of
violations of mandatory health or safety standards that are of
such nature as could have significantly and substantially
contributed to the cause and effect of coal or other mine health
or safety hazards under section 104(e) of the Federal Mine
Safety and Health Act of 1977 or (2) the potential to have
such a pattern. In addition, there were no fatalities at
Chevron’s mines during the three months ended
September 30, 2010.
As of September 30, 2010, the company had 49 pending legal
actions before the Federal Mine Safety and Health Review
Commission, representing contests of citations, orders and
proposed penalties.
45
Table of Contents
| Item 6. | Exhibits |
|
Exhibit
|
||
| Number | Description | |
|
(3.1)
|
By-laws of Chevron Corporation, as amended September 29, 2010, filed as Exhibit 3.1 to Chevron Corporation’s Current Report on Form 8-K dated September 29, 2010, and incorporated herein by reference. | |
|
(4)
|
Pursuant to the Instructions to Exhibits, certain instruments defining the rights of holders of long-term debt securities of the company and its consolidated subsidiaries are not filed because the total amount of securities authorized under any such instrument does not exceed 10 percent of the total assets of the corporation and its subsidiaries on a consolidated basis. A copy of such instrument will be furnished to the Commission upon request. | |
|
(12.1)
|
Computation of Ratio of Earnings to Fixed Charges | |
|
(31.1)
|
Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Executive Officer | |
|
(31.2)
|
Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Financial Officer | |
|
(32.1)
|
Section 1350 Certification by the company’s Chief Executive Officer | |
|
(32.2)
|
Section 1350 Certification by the company’s Chief Financial Officer | |
|
(101.INS)
|
XBRL Instance Document | |
|
(101.SCH)
|
XBRL Schema Document | |
|
(101.CAL)
|
XBRL Calculation Linkbase Document | |
|
(101.LAB)
|
XBRL Label Linkbase Document | |
|
(101.PRE)
|
XBRL Presentation Linkbase Document | |
|
(101.DEF)
|
XBRL Definition Linkbase Document |
Attached as Exhibit 101 to this report are documents
formatted in XBRL (Extensible Business Reporting Language).
Users of this data are advised pursuant to Rule 406T of
Regulation S-T
that the interactive data file is deemed not filed or part of a
registration statement or prospectus for purposes of
section 11 or 12 of the Securities Act of 1933, is deemed
not filed for purposes of section 18 of the Securities
Exchange Act of 1934, and otherwise not subject to liability
under these sections. The financial information contained in the
XBRL-related documents is “unaudited” or
“unreviewed.”
46
Table of Contents
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of
1934, the Registrant has duly caused this report to be signed on
its behalf by the undersigned thereunto duly authorized.
Chevron Corporation
(Registrant)
/s/
Matthew
J. Foehr
Matthew J. Foehr, Vice President and Comptroller
(Principal Accounting Officer and
Duly Authorized Officer)
Date: November 5, 2010
47
Table of Contents
EXHIBIT INDEX
|
Exhibit
|
||
| Number | Description | |
|
(3.1)
|
By-laws of Chevron Corporation, as amended September 29, 2010, filed as Exhibit 3.1 to Chevron Corporation’s Current Report on Form 8-K dated September 29, 2010, and incorporated herein by reference. | |
|
(4)
|
Pursuant to the Instructions to Exhibits, certain instruments defining the rights of holders of long-term debt securities of the company and its consolidated subsidiaries are not filed because the total amount of securities authorized under any such instrument does not exceed 10 percent of the total assets of the corporation and its subsidiaries on a consolidated basis. A copy of such instrument will be furnished to the Commission upon request. | |
|
(12.1)*
|
Computation of Ratio of Earnings to Fixed Charges | |
|
(31.1)*
|
Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Executive Officer | |
|
(31.2)*
|
Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Financial Officer | |
|
(32.1)*
|
Section 1350 Certification by the company’s Chief Executive Officer | |
|
(32.2)*
|
Section 1350 Certification by the company’s Chief Financial Officer | |
|
(101.INS)*
|
XBRL Instance Document | |
|
(101.SCH)*
|
XBRL Schema Document | |
|
(101.CAL)*
|
XBRL Calculation Linkbase Document | |
|
(101.LAB)*
|
XBRL Label Linkbase Document | |
|
(101.PRE)*
|
XBRL Presentation Linkbase Document | |
|
(101.DEF)*
|
XBRL Definition Linkbase Document |
Attached as Exhibit 101 to this report are documents
formatted in XBRL (Extensible Business Reporting Language).
Users of this data are advised pursuant to Rule 406T of
Regulation S-T
that the interactive data file is deemed not filed or part of a
registration statement or prospectus for purposes of
section 11 or 12 of the Securities Act of 1933, is deemed
not filed for purposes of section 18 of the Securities
Exchange Act of 1934, and otherwise not subject to liability
under these sections. The financial information contained in the
XBRL-related documents is “unaudited” or
“unreviewed.”
| * | Filed herewith. |
Copies of above exhibits not contained herein are available to
any security holder upon written request to the Corporate
Governance Department, Chevron Corporation, 6001 Bollinger
Canyon Road, San Ramon, California
94583-2324.
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TABLE OF CONTENTS
Part IprintItem 1. Consolidated Financial StatementsprintNote 1. Interim Financial StatementsprintNote 2. Time DepositsprintNote 3. Noncontrolling InterestsprintNote 4. Information Relating To The Consolidated Statement Of Cash FlowsprintNote 5. Operating Segments and Geographic DataprintNote 6. Summarized Financial Data Chevron U.s.a. IncprintNote 7. Summarized Financial Data Chevron Transport CorporationprintNote 8. Income TaxesprintNote 9. Employee BenefitsprintNote 10. Accounting For Suspended Exploratory WellsprintNote 11. LitigationprintNote 12. Other Contingencies and CommitmentsprintNote 13. Fair Value MeasurementsprintNote 14. Derivative Instruments and Hedging ActivitiesprintNote 15. New Accounting StandardsprintNote 16. Restructuring and Reorganization CostsprintNote 17. Asset Retirement ObligationsprintItem 2. Management S Discussion and Analysis Of Financial Condition and Results Of OperationsprintItem 3. Quantitative and Qualitative Disclosures About Market RiskprintItem 4. Controls and ProceduresprintPart IIprintItem 1. Legal ProceedingsprintItem 1A. Risk FactorsprintItem 2. Unregistered Sales Of Equity Securities and Use Of ProceedsprintItem 5. Other InformationprintItem 6. Exhibitsprint