10-Q 1 cvx-06302014x10qdoc.htm 10-Q CVX-06.30.2014-10Q DOC
 
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-Q
 
þ
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2014
or
o
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 Number)
6001 Bollinger Canyon Road,
San Ramon, California
  
94583-2324
(Zip Code)
(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.
Large accelerated filer þ
  
Accelerated filer o
  
Non-accelerated filer o
  
Smaller reporting company o
 
  
(Do not check if a smaller reporting company)
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).     Yes  o       No  þ
Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date:
 
Class
 
Outstanding as of June 30, 2014
Common stock, $.75 par value
 
1,898,931,825
 



INDEX
 
 
 
Page No.
 
2
PART I
FINANCIAL INFORMATION
Item 1.
 
 
Consolidated Statement of Income for the Three and Six Months Ended June 30, 2014, and 2013
3
 
Consolidated Statement of Comprehensive Income for the Three and Six Months Ended June 30, 2014, and 2013
4
 
Consolidated Balance Sheet at June 30, 2014, and December 31, 2013
5
 
Consolidated Statement of Cash Flows for the Six Months Ended June 30, 2014, and 2013
6
 
7-24
Item 2.
25-38
Item 3.
38
Item 4.
38
PART II
OTHER INFORMATION
Item 1.
39
Item 1A.
39
Item 2.
40
Item 4.
40
Item 6.
40
41
Exhibits:
Computation of Ratio of Earnings to Fixed Charges
43
Rule 13a-14(a)/15d-14(a) Certifications
44-45
Section 1350 Certifications
46-47

1


CAUTIONARY STATEMENTS RELEVANT TO FORWARD-LOOKING INFORMATION
FOR THE PURPOSE OF “SAFE HARBOR” PROVISIONS OF THE
PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995
This quarterly report on Form 10-Q of Chevron Corporation contains forward-looking statements relating to 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,” “forecasts,” “projects,” “believes,” “seeks,” “schedules,” “estimates,” “may,” “could,” “budgets,” “outlook” 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, many 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 chemicals margins; actions of competitors or regulators; timing of exploration expenses; timing of crude oil liftings; the competitiveness of alternate-energy sources or product substitutes; technological developments; the results of operations and financial condition of equity affiliates; the inability or failure of the company’s joint-venture partners to fund their share of operations and development activities; the potential failure to achieve expected net production from existing and future crude oil and natural gas development projects; potential delays in the development, construction or start-up of planned projects; the potential disruption or interruption of the company’s 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 required by 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 27 through 29 of the company’s 2013 Annual Report on Form 10-K. In addition, such results could be affected by general domestic and international economic and political conditions. Other unpredictable or unknown factors not discussed in this report could also have material adverse effects on forward-looking statements.


2


PART I.
FINANCIAL INFORMATION
 
Item 1.
Consolidated Financial Statements
CHEVRON CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF INCOME
(Unaudited)
 
 
Three Months Ended
June 30
 
Six Months Ended
June 30
 
2014
 
2013
 
2014
 
2013
 
(Millions of dollars, except per-share amounts)
Revenues and Other Income
 
 
 
 
 
Sales and other operating revenues*
$
55,583

 
$
55,307

 
$
106,561

 
$
109,603

Income from equity affiliates
1,709

 
1,784

 
3,631

 
4,068

Other income
646

 
278

 
1,011

 
516

Total Revenues and Other Income
57,938

 
57,369

 
111,203

 
114,187

Costs and Other Deductions
 
 
 
 
 
 
 
Purchased crude oil and products
33,844

 
34,273

 
64,667

 
67,183

Operating expenses
6,287

 
6,278

 
12,310

 
12,040

Selling, general and administrative expenses
1,077

 
1,139

 
2,004

 
2,137

Exploration expenses
694

 
329

 
1,109

 
576

Depreciation, depletion and amortization
3,842

 
3,412

 
7,972

 
6,893

Taxes other than on income*
3,167

 
3,349

 
6,186

 
6,486

Total Costs and Other Deductions
48,911

 
48,780

 
94,248

 
95,315

Income Before Income Tax Expense
9,027

 
8,589

 
16,955

 
18,872

Income Tax Expense
3,337

 
3,185

 
6,744

 
7,229

Net Income
5,690

 
5,404

 
10,211

 
11,643

Less: Net income attributable to noncontrolling interests
25

 
39

 
34

 
100

Net Income Attributable to Chevron Corporation
$
5,665

 
$
5,365

 
$
10,177

 
$
11,543

Per Share of Common Stock:
 
 
 
 
 
 
 
Net Income Attributable to Chevron Corporation
 
 
 
 
 
 
 
— Basic
$
3.00

 
$
2.80

 
$
5.38

 
$
6.00

— Diluted
$
2.98

 
$
2.77

 
$
5.34

 
$
5.95

Dividends
$
1.07

 
$
1.00

 
$
2.07

 
$
1.90

Weighted Average Number of Shares Outstanding (000s)
 
 
 
 
 
 
 
— Basic
1,887,543

 
1,921,391

 
1,891,266

 
1,925,181

— Diluted
1,902,321

 
1,936,783

 
1,905,853

 
1,940,337

* Includes excise, value-added and similar taxes:
$
2,120

 
$
2,108

 
$
4,066

 
$
4,141


See accompanying notes to consolidated financial statements.

3


CHEVRON CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
(Unaudited)

 
Three Months Ended
June 30
 
Six Months Ended
June 30
 
2014
 
2013
 
2014
 
2013
 
(Millions of dollars)
Net Income
$
5,690

 
$
5,404

 
$
10,211

 
$
11,643

Currency translation adjustment
8

 
42

 
(30
)
 
31

Unrealized holding gain (loss) on securities:
 
 
 
 
 
 
 
Net gain (loss) arising during period
4

 
(6
)
 
8

 
(7
)
Derivatives:
 
 
 
 
 
 
 
Net derivatives (loss) gain on hedge transactions
(79
)
 
2

 
(82
)
 
2

Reclassification to net income of net realized loss (gain)

 
5

 
(1
)
 

Income tax benefit (expense) on derivatives transactions
28

 
(3
)
 
29

 
(1
)
Total
(51
)
 
4

 
(54
)
 
1

Defined benefit plans:
 
 
 
 
 
 
 
Actuarial loss:
 
 
 
 
 
 
 
Amortization to net income of net actuarial and settlement losses
114

 
232

 
225

 
459

Prior service cost:
 
 
 
 
 
 
 
Amortization to net income of net prior service costs (credits)
7

 
(7
)
 
13

 
(14
)
Defined benefit plans sponsored by equity affiliates
6

 
11

 
12

 
(9
)
Income tax expense on defined benefit plans
(51
)
 
(85
)
 
(92
)
 
(170
)
Total
76

 
151

 
158

 
266

Other Comprehensive Gain, Net of Tax
37

 
191

 
82

 
291

Comprehensive Income
5,727

 
5,595

 
10,293

 
11,934

Comprehensive income attributable to noncontrolling interests
(25
)
 
(39
)
 
(34
)
 
(100
)
Comprehensive Income Attributable to Chevron Corporation
$
5,702

 
$
5,556

 
$
10,259

 
$
11,834


See accompanying notes to consolidated financial statements.

4


CHEVRON CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Unaudited)
 
At June 30
2014
 
At December 31
2013
 
(Millions of dollars, except per-share amounts)
ASSETS
 
  
Cash and cash equivalents
$
13,959

 
$
16,245

Time deposits
8

 
8

Marketable securities
268

 
263

Accounts and notes receivable, net
21,578

 
21,622

Inventories
 
 
 
Crude oil and petroleum products
4,606

 
3,879

Chemicals
479

 
491

Materials, supplies and other
2,130

 
2,010

Total inventories
7,215

 
6,380

Prepaid expenses and other current assets
5,892

 
5,732

Total Current Assets
48,920

 
50,250

Long-term receivables, net
3,034

 
2,833

Investments and advances
25,923

 
25,502

Properties, plant and equipment, at cost
312,922

 
296,433

Less: Accumulated depreciation, depletion and amortization
138,868

 
131,604

Properties, plant and equipment, net
174,054

 
164,829

Deferred charges and other assets
5,493

 
5,120

Goodwill
4,621

 
4,639

Assets held for sale

 
580

Total Assets
$
262,045

 
$
253,753

LIABILITIES AND EQUITY
 
  
Short-term debt
$
3,498

 
$
374

Accounts payable
23,623

 
22,815

Accrued liabilities
5,041

 
5,402

Federal and other taxes on income
2,900

 
3,092

Other taxes payable
1,266

 
1,335

Total Current Liabilities
36,328

 
33,018

Long-term debt
19,960

 
19,960

Capital lease obligations
90

 
97

Deferred credits and other noncurrent obligations
22,888

 
22,982

Noncurrent deferred income taxes
22,017

 
21,301

Noncurrent employee benefit plans
6,015

 
5,968

Total Liabilities
107,298

 
103,326

Preferred stock (authorized 100,000,000 shares, $1.00 par value, none issued)

 

Common stock (authorized 6,000,000,000 shares; $0.75 par value;
     2,442,676,580 shares issued at June 30, 2014, and December 31, 2013)
1,832

 
1,832

Capital in excess of par value
15,890

 
15,713

Retained earnings
179,939

 
173,677

Accumulated other comprehensive loss
(3,497
)
 
(3,579
)
Deferred compensation and benefit plan trust
(240
)
 
(240
)
Treasury stock, at cost (543,744,755 and 529,073,512 shares at June 30, 2014,
     and December 31, 2013, respectively)
(40,343
)
 
(38,290
)
Total Chevron Corporation Stockholders’ Equity
153,581

 
149,113

Noncontrolling interests
1,166

 
1,314

Total Equity
154,747

 
150,427

Total Liabilities and Equity
$
262,045

 
$
253,753


See accompanying notes to consolidated financial statements.

5


CHEVRON CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CASH FLOWS
(Unaudited)


 
Six Months Ended
June 30
 
2014
 
2013
 
(Millions of dollars)
Operating Activities
 
 
 
Net Income
$
10,211

 
$
11,643

Adjustments
 
 
 
Depreciation, depletion and amortization
7,972

 
6,893

Dry hole expense
495

 
79

Distributions less than income from equity affiliates
(839
)
 
(1,118
)
Net before-tax gains on asset retirements and sales
(838
)
 
(175
)
Net foreign currency effects
101

 
(138
)
Deferred income tax provision
505

 
32

Net increase in operating working capital
(741
)
 
(2,515
)
Increase in long-term receivables
(196
)
 
(56
)
Net (increase) decrease in other deferred charges
(79
)
 
68

Cash contributions to employee pension plans
(159
)
 
(610
)
Other
(134
)
 
131

Net Cash Provided by Operating Activities
16,298

 
14,234

Investing Activities
 
 
 
Capital expenditures
(17,475
)
 
(16,765
)
Proceeds and deposits related to asset sales
1,623

 
641

Net purchases of time deposits

 
(700
)
Net sales of marketable securities

 
2

Net repayment of loans by equity affiliates
100

 
162

Net (purchases) sales of other short-term investments
(26
)
 
189

Net Cash Used for Investing Activities
(15,778
)
 
(16,471
)
Financing Activities
 
 
 
Net borrowings of short-term obligations
3,123

 
1,903

Proceeds from issuance of long-term debt

 
6,000

Repayments of long-term debt and other financing obligations
(20
)
 
(110
)
Cash dividends — common stock
(3,914
)
 
(3,656
)
Distributions to noncontrolling interests
(2
)
 
(73
)
Net purchases of treasury shares
(2,019
)
 
(2,028
)
Net Cash Used for Financing Activities
(2,832
)
 
2,036

Effect of Exchange Rate Changes on Cash and Cash Equivalents
26

 
(108
)
Net Change in Cash and Cash Equivalents
(2,286
)
 
(309
)
Cash and Cash Equivalents at January 1
16,245

 
20,939

Cash and Cash Equivalents at June 30
$
13,959

 
$
20,630


See accompanying notes to consolidated financial statements.

6


NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Note 1. Interim Financial Statements
The accompanying consolidated financial statements of Chevron Corporation and its subsidiaries (the company) have not been audited by an independent registered public accounting firm. In the opinion of the company’s management, the interim data includes all adjustments necessary for a fair statement of the results for the interim periods. These adjustments were of a normal recurring nature. The results for the three- and six-month periods ended June 30, 2014, are not necessarily indicative of future financial results. The term “earnings” is defined as net income attributable to Chevron Corporation.
Certain notes and other information have been condensed or omitted from the interim financial statements presented in this Quarterly Report on Form 10-Q. Therefore, these financial statements should be read in conjunction with the company’s 2013 Annual Report on Form 10-K.

Note 2. Changes in Accumulated Other Comprehensive Losses
The change in Accumulated Other Comprehensive Losses (AOCL) presented on the Consolidated Balance Sheet and the impact of significant amounts reclassified from AOCL on information presented in the Consolidated Statement of Income for the six months ending June 30, 2014, are reflected in the table below.
Changes in Accumulated Other Comprehensive Income (Loss) by Component (1) 
(Millions of Dollars)
 
 
Six Months Ended June 30, 2014
 
 
Currency Translation Adjustment
 
Unrealized Holding Gains (Losses) on Securities
 
Derivatives
 
Defined Benefit Plans
 
Total
 
 

Balance at January 1
 
$
(23
)
 
$
(6
)
 
$
52

 
$
(3,602
)
 
$
(3,579
)
Components of Other Comprehensive
    Income (Loss):
 
 
 
 
 
 
 
 
    Before Reclassifications
 
(30
)
 
8

 
(53
)
 
9

 
(66
)
    Reclassifications (2)
 

 

 
(1
)
 
149

 
148

Net Other Comprehensive Income (Loss)
 
(30
)
 
8

 
(54
)
 
158

 
82

Balance at June 30
 
$
(53
)
 
$
2

 
$
(2
)
 
$
(3,444
)
 
$
(3,497
)
_________________________________
(1) All amounts are net of tax.
(2) Refer to Note 9, Employee Benefits for reclassified components totaling $238 million that are included in employee benefit costs for the six months ending June 30, 2014. Related income taxes for the same period, totaling $89 million, are reflected in Income Tax Expense on the Consolidated Statement of Income. All other reclassified amounts were insignificant.


7

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


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 amount of consolidated net income attributable to the parent and the noncontrolling interests are both presented on the face of the Consolidated Statement of Income.
Activity for the equity attributable to noncontrolling interests for the first six months of 2014 and 2013 is as follows:
 
2014
 
2013
 
Chevron
Corporation
Stockholders’ Equity
 
Non-controlling
Interest
 
Total
Equity
 
Chevron
Corporation
Stockholders’ Equity
 
Non-controlling
Interest
 
Total
Equity
 
(Millions of dollars)
Balance at January 1
$
149,113

 
$
1,314

 
$
150,427

 
$
136,524

 
$
1,308

 
$
137,832

Net income
10,177

 
34

 
10,211

 
11,543

 
100

 
11,643

Dividends
(3,916
)
 

 
(3,916
)
 
(3,659
)
 

 
(3,659
)
Distributions to noncontrolling interests

 
(2
)
 
(2
)
 

 
(73
)
 
(73
)
Treasury shares, net
(2,053
)
 

 
(2,053
)
 
(2,059
)
 

 
(2,059
)
Other changes, net*
260

 
(180
)
 
80

 
492

 
(12
)
 
480

Balance at June 30
$
153,581

 
$
1,166

 
$
154,747

 
$
142,841

 
$
1,323

 
$
144,164

 _________________________________
* Includes components of comprehensive income, which are disclosed separately in the Consolidated Statement of Comprehensive Income.

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:
 
Six Months Ended
June 30
 
2014
 
2013
 
(Millions of dollars)
Decrease in accounts and notes receivable
$
145

 
$
504

Increase in inventories
(835
)
 
(1,279
)
(Increase) decrease in prepaid expenses and other current assets
(184
)
 
505

Increase (decrease) in accounts payable and accrued liabilities
347

 
(1,535
)
Decrease in income and other taxes payable
(214
)
 
(710
)
Net increase in operating working capital
$
(741
)
 
$
(2,515
)
The “Net increase in operating working capital” includes reductions of $54 million and $55 million for excess income tax benefits associated with stock options exercised during the six months ended June 30, 2014, and 2013, respectively. These amounts are offset by an equal amount in “Net purchases of treasury shares.”
“Net Cash Provided by Operating Activities” included the following cash payments for income taxes:
 
Six Months Ended
June 30
 
2014
 
2013
 
(Millions of dollars)
Income taxes
$
6,026

 
$
7,565


8

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


"Other" includes changes in postretirement benefits obligations and other long-term liabilities.
Information related to "Restricted Cash" is included on page 22 in Note 12 under the heading "Restricted Cash."
The “Net purchases of time deposits” consisted of the following gross amounts:
 
Six Months Ended
June 30
 
2014
 
2013
 
(Millions of dollars)
Time deposits purchased
$
(308
)
 
$
(1,608
)
Time deposits matured
308

 
908

Net purchases of time deposits
$

 
$
(700
)
The “Net sales of marketable securities” consisted of the following gross amounts:
 
Six Months Ended
June 30
 
2014
 
2013
 
(Millions of dollars)
Marketable securities purchased
$
(4
)
 
$
(5
)
Marketable securities sold
4

 
7

Net sales of marketable securities
$

 
$
2

The “Net purchases of treasury shares” represents the cost of common shares acquired less the cost of shares issued for share-based compensation plans. Purchases totaled $2.5 billion for the first six months in both 2014 and 2013. During the first six months of 2014 and 2013, the company purchased 20.8 million and 21.1 million common shares under its ongoing share repurchase program, respectively, for $2.5 billion in each corresponding period.
The major components of “Capital expenditures” and the reconciliation of this amount to the capital and exploratory expenditures, including equity affiliates, are as follows:
 
Six Months Ended
June 30
 
2014
 
2013
 
(Millions of dollars)
Additions to properties, plant and equipment
$
17,019

 
$
16,334

Additions to investments
221

 
472

Current year dry hole expenditures
251

 
18

Payments for other liabilities and assets, net
(16
)
 
(59
)
Capital expenditures
17,475

 
16,765

Expensed exploration expenditures
614

 
497

Assets acquired through capital lease obligations
10

 
2

Capital and exploratory expenditures, excluding equity affiliates
18,099

 
17,264

Company’s share of expenditures by equity affiliates
1,517

 
1,070

Capital and exploratory expenditures, including equity affiliates
$
19,616

 
$
18,334



9

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


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.” Upstream operations consist primarily of exploring for, developing and producing crude oil and natural gas; liquefaction, transportation and regasification associated with liquefied natural gas (LNG); transporting crude oil by major international oil export pipelines; processing, transporting, storage and marketing of natural gas; and a gas-to-liquids project. Downstream operations consist primarily of refining of crude oil into petroleum products; marketing of crude oil and refined products; transporting of crude oil and refined products by pipeline, marine vessel, motor equipment and rail car; and manufacturing and marketing of commodity petrochemicals, plastics for industrial uses, and fuel and lubricant additives. All Other activities of the company include mining activities, power and energy services, worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities, and technology companies.
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). 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, 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 segment’s operating activities and financial performance. The CODM approves annual capital and exploratory budgets at the reportable segment level, as well as reviews capital and exploratory funding for major projects and approves major changes to the annual capital and exploratory budgets. However, business-unit managers within the operating segments are directly responsible for decisions relating to project implementation and all other matters connected with daily operations. Company officers who are members of the EXCOM also have individual management responsibilities and participate in other committees for purposes other than acting as the CODM.
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).


10

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


Segment Earnings The company evaluates the performance of its operating segments on an after-tax basis, without considering the effects of debt financing interest expense or investment interest income, both of which are managed by the company on a worldwide basis. Corporate administrative costs and assets are not allocated to the operating segments. However, operating segments are billed for the direct use of corporate services. Nonbillable costs remain at the corporate level in “All Other.” Earnings by major operating area for the three- and six-month periods ended June 30, 2014, and 2013, are presented in the following table:
 
Three Months Ended
June 30
 
Six Months Ended
June 30
Segment Earnings*
2014
 
2013
 
2014
 
2013
 
(Millions of dollars)
Upstream
 
 
 
 
 
 
 
United States
$
1,054

 
$
1,083

 
$
1,966

 
$
2,215

International
4,210

 
3,866

 
7,605

 
8,650

Total Upstream
5,264

 
4,949

 
9,571

 
10,865

Downstream
 
 
 
 
 
 
 
United States
517

 
138

 
939

 
273

International
204

 
628

 
492

 
1,194

Total Downstream
721

 
766

 
1,431

 
1,467

Total Segment Earnings
5,985

 
5,715

 
11,002

 
12,332

All Other
 
 
 
 
 
 
 
Interest Income
21

 
18

 
38

 
39

Other
(341
)
 
(368
)
 
(863
)
 
(828
)
Net Income Attributable to Chevron Corporation
$
5,665

 
$
5,365

 
$
10,177

 
$
11,543


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 activities; power and energy services; technology companies; and assets of the corporate administrative functions. Segment assets at June 30, 2014, and December 31, 2013, are as follows:
 
Segment Assets*
At June 30
2014
 
At December 31
2013
 
(Millions of dollars)
Upstream
 
 
 
United States
$
46,748

 
$
45,436

International
145,352

 
137,096

Goodwill
4,621

 
4,639

Total Upstream
196,721

 
187,171

Downstream
 
 
 
United States
24,216

 
23,829

International
21,360

 
20,268

Total Downstream
45,576

 
44,097

Total Segment Assets
242,297

 
231,268

All Other
 
 
 
United States
6,547

 
7,326

International
13,201

 
15,159

Total All Other
19,748

 
22,485

Total Assets — United States
77,511

 
76,591

Total Assets — International
179,913

 
172,523

Goodwill
4,621

 
4,639

Total Assets
$
262,045

 
$
253,753


11

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


Segment Sales and Other Operating Revenues Segment sales and other operating revenues, including internal transfers, for the three- and six-month periods ended June 30, 2014, and 2013, 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 activities, power and energy services, insurance operations, real estate activities, and technology companies.

 
Three Months Ended
June 30
 
Six Months Ended
June 30
 Sales and Other Operating Revenues*
2014
 
2013
 
2014
 
2013
 
(Millions of dollars)
Upstream
 
 
 
 
 
 
 
United States
$
5,965

 
$
6,413

 
$
12,710

 
$
12,680

International
13,454

 
11,746

 
25,335

 
24,657

Subtotal
19,419

 
18,159

 
38,045

 
37,337

Intersegment Elimination — United States
(4,260
)
 
(4,217
)
 
(8,192
)
 
(8,411
)
Intersegment Elimination — International
(6,597
)
 
(7,449
)
 
(12,359
)
 
(15,805
)
Total Upstream
8,562

 
6,493

 
17,494

 
13,121

Downstream
 
 
 
 
 
 
 
United States
21,202

 
21,555

 
41,420

 
41,985

International
28,599

 
27,222

 
52,403

 
54,400

Subtotal
49,801

 
48,777

 
93,823

 
96,385

Intersegment Elimination — United States
(7
)
 
(11
)
 
(12
)
 
(22
)
Intersegment Elimination — International
(2,849
)
 
(26
)
 
(4,894
)
 
(42
)
Total Downstream
46,945

 
48,740

 
88,917

 
96,321

All Other
 
 
 
 
 
 
 
United States
486

 
449

 
875

 
827

International
8

 
9

 
13

 
15

Subtotal
494

 
458

 
888

 
842

Intersegment Elimination — United States
(411
)
 
(375
)
 
(726
)
 
(667
)
Intersegment Elimination — International
(7
)
 
(9
)
 
(12
)
 
(14
)
Total All Other
76

 
74

 
150

 
161

Sales and Other Operating Revenues
 
 
 
 
 
 
 
United States
27,653

 
28,417

 
55,005

 
55,492

International
42,061

 
38,977

 
77,751

 
79,072

Subtotal
69,714

 
67,394

 
132,756

 
134,564

Intersegment Elimination — United States
(4,678
)
 
(4,603
)
 
(8,930
)
 
(9,100
)
Intersegment Elimination — International
(9,453
)
 
(7,484
)
 
(17,265
)
 
(15,861
)
Total Sales and Other Operating Revenues
$
55,583

 
$
55,307

 
$
106,561

 
$
109,603

* Effective January 1, 2014, International Upstream prospectively includes selected amounts previously recognized in International Downstream, which are not material to the company’s results of operations or financial position.



12

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:

Six Months Ended
June 30
 
2014
 
2013
 
(Millions of dollars)
   Sales and other operating revenues
$
84,841

 
$
85,598

   Costs and other deductions
82,242

 
83,253

   Net income attributable to CUSA
2,438

 
2,037

 
At June 30
2014
 
At December 31
2013
 
(Millions of dollars)
   Current assets
$
17,551

 
$
17,626

   Other assets
59,553

 
57,288

   Current liabilities
18,882

 
17,486

   Other liabilities
28,388

 
28,119

   Total CUSA net equity
$
29,834

 
$
29,309

   Memo: Total debt
$
14,478

 
$
14,482


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 from providing transportation services to other Chevron companies. Chevron Corporation has fully and unconditionally guaranteed this subsidiary’s obligations in connection with certain debt securities.
The summarized financial information for CTC and its consolidated subsidiaries is as follows:
 
Three Months Ended
June 30
 
Six Months Ended
June 30
 
2014
 
2013
 
2014
 
2013
 
(Millions of dollars)
   Sales and other operating revenues
$
133

 
$
120

 
$
306

 
$
251

   Costs and other deductions
176

 
164

 
375

 
336

   Net loss attributable to CTC
(43
)
 
(43
)
 
(69
)
 
(84
)


At June 30
2014

At December 31
2013
 
(Millions of dollars)
   Current assets
$
204

 
$
221

   Other assets
728

 
549

   Current liabilities
73

 
94

   Other liabilities
1,161

 
911

   Total CTC net deficit
$
(302
)

$
(235
)
There were no restrictions on CTC’s ability to pay dividends or make loans or advances at June 30, 2014.


13

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


Note 8. Income Taxes
Taxes on income for the second quarter and first six months of 2014 were $3.3 billion and $6.7 billion, respectively, compared with $3.2 billion and $7.2 billion for the corresponding periods in 2013. The associated effective tax rates (calculated as the amount of Income Tax Expense divided by Income Before Income Tax Expense) for the second quarters of 2014 and 2013 were 37 percent in each period. For the comparative six-month periods, the effective tax rates were 40 percent and 38 percent, respectively.

For the quarterly and six-month comparisons, the effects on the effective tax rate of the sale of interests in Chad and Cameroon were substantially offset by foreign currency remeasurement impacts between periods. For the six-month comparative period, the increase in effective tax rate was primarily due to the net impact of changes in equity earnings, jurisdictional mix, and ongoing and one-time tax items.
Tax positions for Chevron and its subsidiaries and affiliates are subject to income tax audits by many tax jurisdictions throughout the world. For the company’s major tax jurisdictions, examinations of tax returns for certain prior tax years had not been completed as of June 30, 2014. For these jurisdictions, the latest years for which income tax examinations had been finalized were as follows: United States — 2008, Nigeria — 2000, Angola — 2001, Saudi Arabia — 2012 and Kazakhstan — 2007.
The company engages in ongoing discussions with tax authorities regarding the resolution of tax matters in the various jurisdictions. Both the outcomes for 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 regarding 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, the company is 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 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 employee benefit (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

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


The components of net periodic benefit costs for 2014 and 2013 are as follows:
 
Three Months Ended
June 30
 
Six Months Ended
June 30
 
2014
 
2013
 
2014
 
2013
 
(Millions of dollars)
Pension Benefits
 
 
 
 
 
 
 
United States
 
 
 
 
 
 
 
Service cost
$
112

 
$
123

 
$
225

 
$
247

Interest cost
123

 
118

 
247

 
236

Expected return on plan assets
(197
)
 
(175
)
 
(394
)
 
(350
)
Amortization of prior service (credits)
(2
)
 
1

 
(4
)
 
1

Amortization of actuarial losses
53

 
122

 
105

 
243

Settlement losses
33

 
57

 
66

 
114

Total United States
122

 
246

 
245

 
491

International
 
 
 
 
 
 
 
Service cost
50

 
49

 
97

 
97

Interest cost
89

 
82

 
173

 
159

Expected return on plan assets
(76
)
 
(68
)
 
(152
)
 
(136
)
Amortization of prior service costs
5

 
5

 
10

 
10

Amortization of actuarial losses
27

 
39

 
51

 
75

Total International
95

 
107

 
179

 
205

Net Periodic Pension Benefit Costs
$
217

 
$
353

 
$
424

 
$
696

Other Benefits*
 
 
 
 
 
 
 
Service cost
$
12

 
$
18

 
$
25

 
$
36

Interest cost
38

 
40

 
75

 
80

Amortization of prior service costs (credits)
4

 
(13
)
 
7

 
(25
)
Amortization of actuarial losses
1

 
14

 
3

 
27

Net Periodic Other Benefit Costs
$
55

 
$
59

 
$
110

 
$
118

_________________________________
* Includes costs for U.S. and international OPEB plans. Obligations for plans outside the United States are not significant relative to the company’s total OPEB obligation.

At the end of 2013, the company estimated it would contribute $700 million to employee pension plans during 2014 (composed of $350 million for the U.S. plans and $350 million for the international plans). Through June 30, 2014, a total of $159 million was contributed (including $63 million to the U.S. plans). Total contributions for the full year are currently estimated to be $450 million ($100 million for the U.S. plans and $350 million for the international plans). The company anticipates it will not make contributions to the primary U.S. pension plan for the remainder of 2014. Actual contribution amounts are dependent upon plan investment returns, changes in pension obligations, regulatory requirements and other economic factors. Additional funding may ultimately be required if investment returns are insufficient to offset increases in plan obligations.
During the first six months of 2014, the company contributed $103 million to its OPEB plans. The company anticipates contributing approximately $112 million during the remainder of 2014.

15

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


Note 10. Litigation
MTBE Chevron and many other companies in the petroleum industry have used methyl tertiary butyl ether (MTBE) as a gasoline additive. Chevron is a party to twelve 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. The company no longer uses MTBE in the manufacture of gasoline in the United States.
Ecuador Chevron is a defendant in a civil lawsuit initiated in the Superior Court of Nueva Loja in Lago Agrio, Ecuador, 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.

16

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


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 remained unresolved. In October 2010, Chevron’s motion to recuse the judge was granted. A new judge took charge of the case and revoked the prior judge’s order closing the evidentiary phase of the case. On December 17, 2010, the judge issued an order closing the evidentiary phase of the case and notifying the parties that he had requested the case file so that he could prepare a judgment.
On February 14, 2011, the provincial court in Lago Agrio rendered an adverse judgment in the case. The court rejected Chevron’s defenses to the extent the court addressed them in its opinion. The judgment assessed approximately $8.6 billion in damages and approximately $900 million as an award for the plaintiffs’ representatives. It also assessed an additional amount of approximately $8.6 billion in punitive damages unless the company issued a public apology within 15 days of the judgment, which Chevron did not do. On February 17, 2011, the plaintiffs appealed the judgment, seeking increased damages, and on March 11, 2011, Chevron appealed the judgment seeking to have the judgment nullified. On January 3, 2012, an appellate panel in the provincial court affirmed the February 14, 2011 decision and ordered that Chevron pay additional attorneys’ fees in the amount of “0.10% of the values that are derived from the decisional act of this judgment.” The plaintiffs filed a petition to clarify and amplify the appellate decision on January 6, 2012, and the court issued a ruling in response on January 13, 2012, purporting to clarify and amplify its January 3, 2012 ruling, which included clarification that the deadline for the company to issue a public apology to avoid the additional amount of approximately $8.6 billion in punitive damages was within 15 days of the clarification ruling, or February 3, 2012. Chevron did not issue an apology because doing so might be mischaracterized as an admission of liability and would be contrary to facts and evidence submitted at trial. On January 20, 2012, Chevron appealed (called a petition for cassation) the appellate panel’s decision to Ecuador’s National Court of Justice. As part of the appeal, Chevron requested the suspension of any requirement that Chevron post a bond to prevent enforcement under Ecuadorian law of the judgment during the cassation appeal. On February 17, 2012, the appellate panel of the provincial court admitted Chevron’s cassation appeal in a procedural step necessary for the National Court of Justice to hear the appeal. The provincial court appellate panel denied Chevron’s request for suspension of the requirement that Chevron post a bond and stated that it would not comply with the First and Second Interim Awards of the international arbitration tribunal discussed below. On March 29, 2012, the matter was transferred from the provincial court to the National Court of Justice, and on November 22, 2012, the National Court agreed to hear Chevron's cassation appeal. On August 3, 2012, the provincial court in Lago Agrio approved a court-appointed liquidator’s report on damages that calculated the total judgment in the case to be $19.1 billion. On November 13, 2013, the National Court ratified the judgment but nullified the $8.6 billion punitive damage assessment, resulting in a judgment of $9.5 billion. On December 23, 2013, Chevron appealed the decision to the Ecuador Constitutional Court, Ecuador's highest court, which agreed to consider the appeal on March 20, 2014.
On July 2, 2013, the provincial court in Lago Agrio issued an embargo order in Ecuador ordering that any funds to be paid by the Government of Ecuador to Chevron to satisfy a $96 million award issued in an unrelated action by an arbitral tribunal presiding in the Permanent Court of Arbitration in The Hague under the Rules of the United Nations Commission on International Trade Law must be paid to the Lago Agrio plaintiffs. The award was issued by the tribunal under the United States-Ecuador Bilateral Investment Treaty in an action filed in 2006 in connection with seven breach of contract cases that Texpet filed against the Government of Ecuador between 1991 and 1993. The Government of Ecuador has moved to set aside the tribunal's award. A Federal District Court for the District of Columbia confirmed the tribunal's award, and the Government of Ecuador has appealed the District Court's decision.
Chevron has no assets in Ecuador and the Lago Agrio plaintiffs’ lawyers have stated in press releases and through other media that they will seek to enforce the Ecuadorian judgment in various countries and otherwise disrupt Chevron’s operations. On May 30, 2012, the Lago Agrio plaintiffs filed an action against Chevron

17

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


Corporation, Chevron Canada Limited, and Chevron Canada Finance Limited in the Ontario Superior Court of Justice in Ontario, Canada, seeking to recognize and enforce the Ecuadorian judgment. On May 1, 2013, the Ontario Superior Court of Justice held that the Court has jurisdiction over Chevron and Chevron Canada Limited for purposes of the action, but stayed the action due to the absence of evidence that Chevron Corporation has assets in Ontario. The Lago Agrio plaintiffs appealed that decision. On December 17, 2013, the Court of Appeals for Ontario affirmed the lower court’s decision on jurisdiction and set aside the stay, allowing the recognition and enforcement action to be heard in the Ontario Superior Court of Justice. Chevron appealed the decision concerning jurisdiction to the Supreme Court of Canada and, on January 16, 2014, the Court of Appeals for Ontario granted Chevron’s motion to stay the recognition and enforcement proceeding pending a decision on the admissibility of the Supreme Court appeal. On April 3, 2014, the Supreme Court of Canada granted Chevron’s and Chevron Canada Limited’s petitions to appeal the Ontario Court of Appeal’s decision. On April 8, 2014, Chevron and Chevron Canada Limited filed their notices of appeal with the Canada Supreme Court.
On June 27, 2012, the Lago Agrio plaintiffs filed an action against Chevron Corporation in the Superior Court of Justice in Brasilia, Brazil, seeking to recognize and enforce the Ecuadorian judgment. On October 15, 2012, the provincial court in Lago Agrio issued an ex parte embargo order that purports to order the seizure of assets belonging to separate Chevron subsidiaries in Ecuador, Argentina and Colombia. On November 6, 2012, at the request of the Lago Agrio plaintiffs, a court in Argentina issued a Freeze Order against Chevron Argentina S.R.L. and another Chevron subsidiary, Ingeniero Norberto Priu, requiring shares of both companies to be "embargoed," requiring third parties to withhold 40 percent of any payments due to Chevron Argentina S.R.L. and ordering banks to withhold 40 percent of the funds in Chevron Argentina S.R.L. bank accounts. On December 14th, 2012, the Argentinean court rejected a motion to revoke the Freeze Order but modified it by ordering that third parties are not required to withhold funds but must report their payments. The court also clarified that the Freeze Order relating to bank accounts excludes taxes. On January 30, 2013, an appellate court upheld the Freeze Order, but on June 4, 2013 the Supreme Court of Argentina revoked the Freeze Order in its entirety. On December 12, 2013, the Lago Agrio plaintiffs served Chevron with notice of their filing of an enforcement proceeding in the National Court, First Instance, of Argentina. Chevron filed its answer on February 27, 2014. Chevron intends to vigorously defend against the proceeding. Chevron continues to believe the provincial court’s judgment is illegitimate and unenforceable in Ecuador, the United States and other countries. The company also believes the judgment is the product of fraud, and contrary to the legitimate scientific evidence. Chevron cannot predict the timing or ultimate outcome of the appeals process in Ecuador or any enforcement action. Chevron expects to continue a vigorous defense of any imposition of liability in the Ecuadorian courts and to contest and defend any and all enforcement actions.
Chevron and Texpet filed an arbitration claim in September 2009 against the Republic of Ecuador before an arbitral tribunal presiding in the Permanent Court of Arbitration in The Hague under the Rules of the United Nations Commission on International Trade Law. The claim alleges violations of the Republic of Ecuador’s obligations under the United States–Ecuador Bilateral Investment Treaty (BIT) and breaches of the settlement and release agreements between the Republic of Ecuador and Texpet (described above), which are investment agreements protected by the BIT. Through the arbitration, Chevron and Texpet are seeking relief against the Republic of Ecuador, including a declaration that any judgment against Chevron in the Lago Agrio litigation constitutes a violation of Ecuador’s obligations under the BIT. On February 9, 2011, the Tribunal issued an Order for Interim Measures, requiring the Republic of Ecuador to take all measures at its disposal to suspend or cause to be suspended the enforcement or recognition within and without Ecuador of any judgment against Chevron in the Lago Agrio case pending further order of the Tribunal. On January 25, 2012, the Tribunal converted the Order for Interim Measures into an Interim Award. Chevron filed a renewed application for further interim measures on January 4, 2012, and the Republic of Ecuador opposed Chevron’s application and requested that the existing Order for Interim Measures be vacated on January 9, 2012. On February 16, 2012, the Tribunal issued a Second Interim Award mandating that the Republic of Ecuador take all measures necessary (whether by its judicial, legislative or executive branches) to suspend or cause to be suspended the enforcement and recognition within and without Ecuador of the judgment against Chevron and, in particular, to preclude any certification by the Republic of Ecuador that would cause the judgment to be enforceable against Chevron. On February 27,

18

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


2012, the Tribunal issued a Third Interim Award confirming its jurisdiction to hear Chevron’s arbitration claims. On February 7, 2013, the Tribunal issued its Fourth Interim Award in which it declared that the Republic of Ecuador “has violated the First and Second Interim Awards under the [BIT], the UNCITRAL Rules and international law in regard to the finalization and enforcement subject to execution of the Lago Agrio Judgment within and outside Ecuador, including (but not limited to) Canada, Brazil and Argentina.” The Tribunal has divided the merits phase of the proceeding into three phases. On September 17, 2013, the Tribunal issued its First Partial Award from Phase One, finding that the settlement agreements between the Republic of Ecuador and Texpet applied to Texpet and Chevron, released Texpet and Chevron from claims based on "collective" or "diffuse" rights arising from Texpet's operations in the former concession area and precluded third parties from asserting collective/diffuse rights environmental claims relating to Texpet's operations in the former concession area, but did not preclude individual claims for personal harm. Chevron expects that the application of this ruling will be considered by the Tribunal in Phase Two, including a determination whether the claims of the Lago Agrio plaintiffs are individual or collective/diffuse. The Tribunal had set Phase Two to begin on January 20, 2014 to hear Chevron's denial of justice claims, but on January 2, 2014, the Tribunal postponed Phase Two and held a procedural hearing on January 20-21, 2014. The Tribunal held a hearing on April 29-30, 2014 to address remaining issues relating to Phase One. It also set a hearing on April 20 to May 6, 2015 to address Phase Two issues. The Tribunal has not set a date for Phase Three, which will be the damages phase of the arbitration.
Through a series of U.S. court proceedings initiated by Chevron to obtain discovery relating to the Lago Agrio litigation and the BIT arbitration, Chevron obtained evidence that it believes shows a pattern of fraud, collusion, corruption, and other misconduct on the part of several lawyers, consultants and others acting for the Lago Agrio plaintiffs. In February 2011, Chevron filed a civil lawsuit in the Federal District Court for the Southern District of New York against the Lago Agrio plaintiffs and several of their lawyers, consultants and supporters, alleging violations of the Racketeer Influenced and Corrupt Organizations Act and other state laws. Through the civil lawsuit, Chevron is seeking relief that includes a declaration that any judgment against Chevron in the Lago Agrio litigation is the result of fraud and other unlawful conduct and is therefore unenforceable. On March 7, 2011, the Federal District Court issued a preliminary injunction prohibiting the Lago Agrio plaintiffs and persons acting in concert with them from taking any action in furtherance of recognition or enforcement of any judgment against Chevron in the Lago Agrio case pending resolution of Chevron’s civil lawsuit by the Federal District Court. On May 31, 2011, the Federal District Court severed claims one through eight of Chevron’s complaint from the ninth claim for declaratory relief and imposed a discovery stay on claims one through eight pending a trial on the ninth claim for declaratory relief. On September 19, 2011, the U.S. Court of Appeals for the Second Circuit vacated the preliminary injunction, stayed the trial on Chevron’s ninth claim, a claim for declaratory relief, that had been set for November 14, 2011, and denied the defendants’ mandamus petition to recuse the judge hearing the lawsuit. The Second Circuit issued its opinion on January 26, 2012 ordering the dismissal of Chevron’s ninth claim for declaratory relief. On February 16, 2012, the Federal District Court lifted the stay on claims one through eight, and on October 18, 2012, the Federal District Court set a trial date of October 15, 2013. On March 22, 2013, Chevron settled its claims against Stratus Consulting, and on April 12, 2013 sworn declarations by representatives of Stratus Consulting were filed with the Court admitting their role and that of the plaintiffs' attorneys in drafting the environmental report of the mining engineer appointed by the provincial court in Lago Agrio. On September 26, 2013, the Second Circuit denied the defendants' Petition for Writ of Mandamus to recuse the judge hearing the case and to collaterally estop Chevron from seeking a declaration that the Lago Agrio judgment was obtained through fraud and other unlawful conduct. The trial commenced on October 15, 2013 and concluded on November 22, 2013. On March 4, 2014, the Federal District Court entered a judgment in favor of Chevron, prohibiting the defendants from seeking to enforce the Lago Agrio judgment in the United States and further prohibiting them from profiting from their illegal acts. The defendants filed their notices of appeal on March 18, 2014.
The ultimate outcome of the foregoing matters, including any financial effect on Chevron, remains uncertain. Management does not believe an estimate of a reasonably possible loss (or a range of loss) can be made in this case. Due to the defects associated with the Ecuadorian judgment, the 2008 engineer’s report on alleged damages

19

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


and the September 2010 plaintiffs’ submission on alleged damages, management does not believe these documents have any utility in calculating a reasonably possible loss (or a range of loss). Moreover, the highly uncertain legal environment surrounding the case provides no basis for management to estimate a reasonably possible loss (or a range of loss).

Note 11. Other Contingencies and Commitments
Income Taxes The company calculates its income tax expense and liabilities quarterly. These liabilities generally are subject to audit and are not finalized with the individual taxing authorities until several years after the end of the annual period for which income taxes have been calculated. Refer to Note 8 on page 14 for a discussion of the periods for which tax returns have been audited for the company’s major tax jurisdictions.
Settlement of open tax years, as well as other tax issues in countries where the company conducts its businesses, are 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.
Guarantees The company and its subsidiaries have certain contingent liabilities with respect to guarantees, direct or indirect, of debt of affiliated companies or third parties. Under the terms of the guarantee arrangements, the company would generally be required to perform should the affiliated company or third party fail to fulfill its obligations under the arrangements. In some cases, the guarantee arrangements may have recourse provisions that would enable the company to recover any payments made under the terms of the guarantees from assets provided as collateral.
Indemnifications 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.
Off-Balance-Sheet Obligations The company and its subsidiaries have certain contingent liabilities with respect to long-term unconditional purchase obligations and commitments, including throughput and take-or-pay agreements, some of which relate to suppliers’ financing arrangements. The agreements typically provide goods and services, such as pipeline and storage capacity, drilling rigs, utilities, and petroleum products, to be used or sold in the ordinary course of the company’s business.
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 activities, 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

20

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


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.
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. Settlement discussions with plaintiffs in the case ended late fourth quarter 2010, and on March 3, 2011, the trial court entered a final judgment and peremptory writ ordering the City to set aside the project EIR and conditional use permits and enjoining Chevron from any further work. On May 23, 2011, the company filed an application with the City Planning Department for a conditional use permit for a revised project to complete construction of the hydrogen plant, certain sulfur removal facilities and related infrastructure. On June 10, 2011, the City published its Notice of Preparation of the revised EIR for the project, and on March 18, 2014, the revised draft EIR was published for public comment. The public comment period closed in May 2014, the final EIR was released on June 9, 2014, and on July 29, 2014, the Richmond City Council certified the EIR and approved a conditional use permit. The company will now seek to secure the further necessary approvals to resume construction. Although the City Council has certified the EIR, management believes the outcomes associated with 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, can be made at this time.
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, and may result in gains or losses in future periods.
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 12. Fair Value Measurements
The three levels of the fair value hierarchy of inputs the company uses to measure the fair value of an asset or liability are described as follows:
Level 1: Quoted prices (unadjusted) in active markets for identical assets and liabilities. For the company, Level 1 inputs include exchange-traded futures contracts for which the parties are willing to transact at the exchange-quoted price and marketable securities that are actively traded.
Level 2: Inputs other than Level 1 that are observable, either directly or indirectly. For the company, Level 2 inputs include quoted prices for similar assets or liabilities, prices obtained through third-party broker quotes and prices that can be corroborated with other observable inputs for substantially the complete term of a contract.
Level 3: Unobservable inputs. The company does not use Level 3 inputs for any of its recurring fair value measurements. Level 3 inputs may be required for the determination of fair value associated with certain nonrecurring measurements of nonfinancial assets and liabilities.

21

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


The fair value hierarchy for assets and liabilities measured at fair value on a recurring basis at June 30, 2014, and December 31, 2013, is as follows:
Assets and Liabilities Measured at Fair Value on a Recurring Basis
(Millions of dollars)
 
At June 30, 2014
 
At December 31, 2013
 
Total
 
Level 1
 
Level 2
 
Level 3
 
Total
 
Level 1
 
Level 2
 
Level 3
Marketable Securities
$
268

 
$
268

 
$

 
$

 
$
263

 
$
263

 
$

 
$

Derivatives
13

 

 
13

 

 
28

 

 
28

 

Total Assets at Fair Value
$
281

 
$
268

 
$
13

 
$

 
$
291

 
$
263

 
$
28

 
$

Derivatives
83

 
63

 
20

 

 
89

 
80

 
9

 

Total Liabilities at Fair Value
$
83

 
$
63

 
$
20

 
$

 
$
89

 
$
80

 
$
9

 
$

Marketable Securities The company calculates fair value for its marketable securities based on quoted market prices for identical assets. The fair values reflect the cash that would have been received if the instruments were sold at June 30, 2014.
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 the offsetting amount to the Consolidated Statement of Income. Derivatives classified as Level 1 include futures, swaps and options contracts traded in active markets such as the New York Mercantile Exchange. Derivatives classified as Level 2 include swaps, options and forward contracts principally with financial institutions and other oil and gas companies, the fair values of which are obtained from third-party broker quotes, industry pricing services and exchanges. The company obtains multiple sources of pricing information for the Level 2 instruments. Since this pricing information is generated from observable market data, it has historically been very consistent. The company does not materially adjust this information.
Assets carried at fair value at June 30, 2014, and December 31, 2013, are as follows:
Cash and Cash Equivalents and Time Deposits 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 $14.0 billion and $16.2 billion at June 30, 2014, and December 31, 2013, respectively. The instruments held in “Time deposits” are bank time deposits with maturities greater than 90 days and had carrying/fair values of $8 million at both June 30, 2014 and December 31, 2013. The fair values of cash, cash equivalents and bank time deposits are classified as Level 1 and reflect the cash that would have been received if the instruments were settled at June 30, 2014.
Restricted Cash had a carrying/fair value of $1.2 billion at both June 30, 2014 and December 31, 2013. At June 30, 2014, restricted cash is classified as Level 1 and includes restricted funds related to certain upstream abandonment activities, tax payments and funds held in escrow for asset acquisitions, which are reported in “Deferred charges and other assets” on the Consolidated Balance Sheet.
Long-Term Debt had a net carrying value, excluding amounts reclassified from short-term, of $12.0 billion at both June 30, 2014, and December 31, 2013. The fair value of long-term debt at June 30, 2014, and December 31, 2013 was $12.4 billion and $12.3 billion, respectively. Long-term debt primarily includes corporate issued bonds. The fair value of corporate bonds is $11.7 billion and classified as Level 1. The fair value of the other bonds is $0.7 billion and classified as Level 2.
The carrying values of other short-term financial assets and liabilities on the Consolidated Balance Sheet approximate their fair values. Fair value remeasurements of other financial instruments at June 30, 2014, and December 31, 2013, were not material.

22

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


The fair value hierarchy for assets and liabilities measured at fair value on a nonrecurring basis at June 30, 2014, is as follows:
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
(Millions of dollars)
 
At June 30, 2014
 
Total
 
Level 1
 
Level 2
 
Level 3
 
Before-Tax Loss
 
 
 
 
 
Three
Months
Ended
 
Six
Months
Ended
 Properties, plant and equipment, net (held and used)
$
19

 
$

 
$

 
$
19

 
$
93

 
$
560

 Properties, plant and equipment, net (held for sale)

 

 

 

 

 

 Investments and advances
1

 

 

 
1

 
4

 
31

 Total Assets at Fair Value
$
20

 
$

 
$

 
$
20

 
$
97

 
$
591

Properties, plant and equipment The company did not have any material impairments of long-lived assets measured at fair value on a nonrecurring basis to report in second quarter 2014.
Investments and advances The company did not have any material impairments of investments and advances measured at fair value on a nonrecurring basis to report in second quarter 2014.

Note 13. Financial and Derivative Instruments
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 hedging instruments, although certain of the company’s affiliates make such a designation. The company’s derivatives are not material to the company’s consolidated 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.
The company uses derivative commodity instruments traded on the New York Mercantile Exchange and on electronic platforms of the Inter-Continental Exchange and Chicago Mercantile Exchange. In addition, the company enters into swap contracts and option contracts principally with major financial institutions and other oil and gas companies in the “over-the-counter” markets, which are governed by International Swaps and Derivatives Association agreements and other master netting arrangements.
Derivative instruments measured at fair value at June 30, 2014, and December 31, 2013, and their classification on the Consolidated Balance Sheet and Consolidated Statement of Income are as follows:
Consolidated Balance Sheet: Fair Value of Derivatives Not Designated as Hedging Instruments
(Millions of Dollars)
Type of
Contract
 
Balance Sheet Classification
 
At June 30
2014
 
At December 31
2013
Commodity
 
Accounts and notes receivable, net
 
$
12

 
$
22

Commodity
 
Long-term receivables, net
 
1

 
6

Total Assets at Fair Value
 
$
13

 
$
28

Commodity
 
Accounts payable
 
$
66

 
$
65

Commodity
 
Deferred credits and other noncurrent obligations
 
17

 
24

Total Liabilities at Fair Value
 
$
83

 
$
89



23

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


Consolidated Statement of Income: The Effect of Derivatives Not Designated as Hedging Instruments
(Millions of dollars)
 
 
 
 
Gain / (Loss)
Three Months Ended
June 30
 
Gain / (Loss)
Six Months Ended
June 30
Type of
Contract
 
Statement of Income Classification
 
2014
 
2013
 
2014
 
2013
Commodity
 
Sales and other operating revenues
 
$
(71
)
 
$
112

 
$
26

 
$
37

Commodity
 
Purchased crude oil and products
 
(8
)
 
(28
)
 
(16
)
 
(32
)
Commodity
 
Other income
 

 
(6
)
 
(23
)
 
(7
)
 
 
 
 
$
(79
)
 
$
78

 
$
(13
)
 
$
(2
)

The table below represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at June 30, 2014, and December 31, 2013.
Consolidated Balance Sheet: The Effect of Netting Derivative Assets and Liabilities
(Millions of dollars)
 
 
Gross Amount Recognized
 
Gross Amounts Offset
 
Net Amounts Presented
 
 Gross Amounts Not Offset
 
Net Amount
At June 30, 2014
 
 
 
 
 
Derivative Assets
 
$
1,384

 
$
1,371

 
$
13

 
$
12

 
$
1

Derivative Liabilities
 
$
1,454

 
$
1,371

 
$
83

 
$

 
$
83

 
 
 
 
 
 
 
 
 
 
 
At December 31, 2013
 
 
 
 
 
 
 
 
 
 
Derivative Assets
 
$
732

 
$
704

 
$
28

 
$
27

 
$
1

Derivative Liabilities
 
$
793

 
$
704

 
$
89

 
$

 
$
89

 
 
 
 
 
 
 
 
 
 
 
Derivative assets and liabilities are classified on the Consolidated Balance Sheet as accounts and notes receivable, long-term receivables, accounts payable, and deferred credits and other noncurrent obligations. Amounts not offset on the Consolidated Balance Sheet represent positions that do not meet all the conditions for "a right of offset."

Note 14. Accounting for Suspended Exploratory Wells
The capitalized cost of suspended wells at June 30, 2014, was $3.9 billion, a net increase of $656 million from year-end 2013, primarily due to drilling activities.

Note 15. New Accounting Standards
Revenue Recognition (Topic 606), Revenue from Contracts with Customers (ASU 2014-09) In May 2014, the FASB issued ASU 2014-09, which becomes effective for the company January 1, 2017. Early adoption is not permitted. The standard provides that an entity should recognize revenue to align with the transfer of promised goods or services to customers in an amount that reflects the consideration that the entity expects to be entitled to receive in exchange for those goods or services. The ASU, which replaces most existing revenue recognition guidance in U.S. GAAP, provides a five-step model for recognition of revenue, guidance on the accounting for certain costs of obtaining or fulfilling contracts with customers and specific disclosure requirements. Transition guidance permits either retrospective application or presentation of the cumulative effect at the adoption date. The company is reviewing the requirements of the ASU to determine the transition method it will apply and to update its assessments developed throughout the FASB’s deliberation period. The company is evaluating the effect of the standard on the company’s consolidated financial statements.


24


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

Second Quarter 2014 Compared with Second Quarter 2013
And Six Months 2014 Compared with Six Months 2013

Key Financial Results
Earnings by Business Segment
 
Three Months Ended
June 30
 
Six Months Ended
June 30
 
2014
 
2013
 
2014
 
2013
 
(Millions of dollars)
Upstream
 
 
 
 
 
 
 
United States
$
1,054

 
$
1,083

 
$
1,966

 
$
2,215

International
4,210

 
3,866

 
7,605

 
8,650

Total Upstream
5,264

 
4,949

 
9,571

 
10,865

Downstream
 
 
 
 
 
 
 
United States
517

 
138

 
939

 
273

International
204

 
628

 
492

 
1,194

Total Downstream
721

 
766

 
1,431

 
1,467

Total Segment Earnings
5,985

 
5,715

 
11,002

 
12,332

All Other
(320
)
 
(350
)
 
(825
)
 
(789
)
Net Income Attributable to Chevron Corporation (1) (2)
$
5,665

 
$
5,365

 
$
10,177

 
$
11,543

____________________
 
 
 
 
 
 
 
(1) Includes foreign currency effects
$
(232
)
 
$
302

 
$
(311
)
 
$
548

(2) Income net of tax; also referred to as “earnings” in the discussions that follow.
 
 
 
 
 
 
Net income attributable to Chevron Corporation for second quarter 2014 was $5.7 billion ($2.98 per share — diluted), versus $5.4 billion ($2.77 per share — diluted) in the corresponding 2013 period. Net income attributable to Chevron Corporation for the first six months of 2014 was $10.2 billion ($5.34 per share — diluted), versus $11.5 billion ($5.95 per share — diluted) in the first six months of 2013.
Upstream earnings in second quarter 2014 were $5.3 billion compared with $4.9 billion a year earlier. The increase between comparative periods was mainly due to higher gains on asset sales and increased crude oil realizations and sales volumes, partly offset by higher depreciation and exploration expenses, along with adverse foreign currency effects. Earnings for the first six months of 2014 were $9.6 billion compared with $10.9 billion a year earlier. Gains from asset sales and higher crude oil realizations were more than offset by higher depreciation, exploration and operating expenses and unfavorable foreign currency effects.
Downstream earnings in second quarter 2014 were $721 million compared with $766 million in the corresponding 2013 period. Higher earnings from the 50 percent-owned Chevron Phillips Chemical Company LLC and stronger margins on refined product sales in the U.S. were more than offset by lower international margins and adverse foreign currency effects. Earnings for the first six months of 2014 were $1.4 billion compared with $1.5 billion in the corresponding 2013 period. Higher margins on refined product sales in the U.S., stronger earnings from the 50 percent-owned Chevron Phillips Chemical Company LLC and gains from asset sales in the U.S. were more than offset by lower international margins and unfavorable changes in effects of foreign currency and derivative instruments.
Refer to pages 29 through 32 for additional discussion of results by business segment and “All Other” activities for second quarter of 2014 versus the same period in 2013.

Business Environment and Outlook
Chevron is a global energy company with substantial business activities in the following countries: Angola, Argentina, Australia, Azerbaijan, Bangladesh, Brazil, Cambodia, Canada, China, Colombia, Democratic

25


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 mostly on the profitability of its upstream and downstream business segments. The biggest factor affecting the results of operations for the company is the price of crude oil. In the downstream business, crude oil is the largest cost component of refined products. Seasonality is not a primary driver of changes in the company’s quarterly earnings during the year.
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.
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. 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. 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.
The company 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. Refer to the "Results of Operations" section, beginning on page 29 for discussions of net gains on asset sales during 2014. Asset dispositions and restructurings may also occur in future periods and could result in significant gains or losses.
The company closely monitors developments in the financial and credit markets, the level of worldwide economic activity, and the implications for the company of movements in prices for crude oil and natural gas. Management takes these developments into account in the conduct of daily operations and for business planning.
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 prices 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 production and 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. Any of these factors could also inhibit the company’s production capacity in an affected region. The company closely monitors developments in the countries in which it operates and holds investments, and seeks to manage risks in operating its facilities and businesses. 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.
The company continues to actively manage its schedule of work, contracting, procurement and supply-chain activities to effectively manage costs. However, price levels for capital and exploratory costs and operating expenses associated with the production of crude oil and natural gas can 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. 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. Capital and exploratory expenditures and operating expenses can also be affected by damage to production facilities caused by severe weather or civil unrest, delays in construction, or other factors.

26



The chart above shows the trend in benchmark prices for Brent crude oil, West Texas Intermediate (WTI) crude oil, and U.S. Henry Hub natural gas. The Brent price averaged $109 per barrel for the full-year 2013. During 2014, Brent averaged $110 per barrel in the second quarter, $109 per barrel for the six-month period, and ended July at about $104. The majority of the company’s equity crude production is priced based on the Brent benchmark. While geopolitical tensions and supply disruptions have supported crude prices in 2014, the price for Brent-related crudes in the Atlantic Basin also reflects continued softness in the global economic recovery, high refinery maintenance in Europe and higher production from Iraq and Iran.
The WTI price averaged $98 per barrel for the full-year 2013. During 2014, WTI averaged $103 per barrel in the second quarter, $101 per barrel for the six-month period and ended July at about $98. WTI traded at a discount to Brent throughout 2013 and the first six months of 2014 due to high inventories and excess crude supply in the U.S. midcontinent market.
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 relative supply/demand balances for each crude type, which are functions of the capacity of refineries that are able to process each as feedstock into high-value light products (motor gasoline, jet fuel, aviation gasoline and diesel fuel). In the first six months of 2014, the differential eased in North America as light sweet crude oil production in the U.S. midcontinent region remained robust, while refinery maintenance dampened demand. Outside of North America, supply disruptions in Libya and elsewhere supported light sweet crude markets relative to heavier, more sour crudes.
Chevron produces or shares in the production of heavy crude oil in California, 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 U.S., prices at Henry Hub averaged $4.86 per thousand cubic feet (MCF) for the first six months of 2014, compared with $3.76 during the first six months of 2013. At the end of July 2014, the Henry Hub spot price was $3.75 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.
Outside the United States, price changes for natural gas depend on a wide range of supply, demand and regulatory circumstances. In some locations, Chevron is investing in long-term projects to install infrastructure to produce and liquefy natural gas for transport by tanker to other markets. International natural gas realizations averaged $6.00 per MCF during the first six months of 2014, unchanged from the same period last year. (See page 35 for the company’s average natural gas realizations for the U.S. and international regions.)
The company’s worldwide net oil-equivalent production in the first six months of 2014 averaged 2.567 million barrels per day. About one-fifth of the company’s net oil-equivalent production in the first six months of 2014 occurred in the OPEC-member countries of Angola, Nigeria, Venezuela and the Partitioned Zone between Saudi Arabia and Kuwait. OPEC quotas had no effect on the company’s net crude oil production for the second quarter or six-month periods of 2014 or 2013. At their June 2014 meeting, members of OPEC supported maintaining the current production quota of 30 million barrels per day, which has been in effect since December 2008.

27


The company estimates that net oil-equivalent production for the full-year 2014 will average about 98 to 99 percent of the previously-announced target of 2.610 million barrels per day, based on an average Brent price of $109 per barrel. This estimate is subject to many factors and uncertainties, including quotas that may be imposed by OPEC; price and other production entitlement effects; changes in fiscal terms or restrictions on the scope of company operations; delays in construction, start-up or ramp-up of projects; 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.
On November 7, 2011, while drilling a development well in the deepwater Frade Field about 75 miles offshore Brazil, an unanticipated pressure spike caused oil to migrate from the well bore through a series of fissures to the sea floor, emitting approximately 2,400 barrels of oil. The source of the seep was substantially contained within four days and the well was plugged and abandoned. On March 14, 2012, the company identified a small, second seep in a different part of the field. No evidence of any coastal or wildlife impacts related to these seeps have emerged. A Brazilian federal district prosecutor filed two civil lawsuits seeking $10.7 billion in damages for each of the two seeps. On October 1, 2013, the Court dismissed the two civil lawsuits and approved a settlement under which Chevron and its consortium partners agreed to spend approximately $43 million on social and environmental programs. On November 11, 2013, the Court announced that the settlement is final. The federal district prosecutor also filed criminal charges against Chevron and eleven Chevron employees. On February 19, 2013, the court dismissed the criminal matter, and on appeal, on October 9, 2013, the appellate court reinstated two of the ten allegations, specifically those charges alleging environmental damage and failure to provide timely notification to authorities. On February 27, 2014, Chevron filed a motion for reconsideration. The company’s ultimate exposure related to the incident is not currently determinable, but could be significant to net income in any one period.
Refer to the “Results of Operations” section on pages 29 through 30 for additional discussion of the company’s upstream business.
Downstream Earnings for the downstream segment are closely tied to margins on the refining, manufacturing and marketing of products that include gasoline, diesel, jet fuel, lubricants, fuel oil, fuel and lubricant additives, and petrochemicals. Industry margins are sometimes volatile and can be affected by the global and regional supply-and-demand balance for refined products and petrochemicals, and by changes in the price of crude oil, other refinery and petrochemical feedstocks, and natural gas. Industry margins can also be influenced by inventory levels, geopolitical events, costs 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, marketing and petrochemical assets, the effectiveness of its 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 refining, marketing and petrochemical assets.
The company’s most significant marketing areas are the West Coast of North America, the U.S. Gulf Coast, Asia and southern Africa. Chevron operates or has significant ownership interests in refineries in each of these areas.
Refer to the “Results of Operations” section on pages 31 through 32 for additional discussion of the company’s downstream operations.
All Other consists of mining activities, power and energy services, worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities, and technology companies.


28


Operating Developments
Noteworthy operating developments for the upstream business in recent months included the following:
Australia — All Gorgon Train 1 and common modules required for first LNG have been delivered and installed on Barrow Island.
Australia — The first deliveries arrived at the Wheatstone Project’s Materials Offloading Facility. Preparations continue for arrival of the first Train 1 process modules later this year.
Chad/Cameroon — Completed the sale of the company’s nonoperated interest in a producing concession in Chad and the related export pipeline interests in Chad and Cameroon for approximately $1.3 billion.
Nigeria — Achieved initial production of product at the Escravos Gas-to-Liquids facility.
United States — Offshore hookup and commissioning is underway at the Jack/St. Malo Project, which remains on track for expected start-up in fourth quarter 2014.
United States — The production platform has been installed offshore at the nonoperated Tubular Bells development, and start-up is expected in third quarter 2014.
In the downstream, commercial production began at the new premium lubricants base oil facility in Pascagoula, Mississippi, and expansion of the Singapore additives plant was completed. Chevron Phillips Chemical Company LLC, the company’s 50 percent-owned affiliate, achieved start-up of the world’s largest on-purpose 1-hexene plant, with a capacity of 250,000 metric tons per year, at its Cedar Bayou complex in Baytown, Texas.
The company purchased $1.25 billion of its common stock in second quarter 2014 under its share repurchase program.

Results of Operations
Business Segments The following section presents the results of operations and variances on an after-tax basis for the company’s business segments — Upstream and Downstream — as well as for “All Other.” (Refer to Note 5, on page 10, for a discussion of the company’s “reportable segments,” as defined under the accounting standards for segment reporting.)
Upstream
 
Three Months Ended
June 30
 
Six Months Ended
June 30
 
2014
 
2013
 
2014
 
2013
 
(Millions of dollars)
     U.S. Upstream Earnings
$
1,054

 
$
1,083

 
$
1,966

 
$
2,215

U.S. upstream earnings of $1.1 billion in second quarter 2014 were down $29 million from the corresponding period in 2013. Earnings decreased due to higher depreciation, exploration and operating expenses of $140 million, $100 million and $60 million, respectively. Partially offsetting these effects were gains on asset sales of $180 million and stronger crude oil and natural gas realizations of $50 million.
U.S. upstream earnings for the first six months of 2014 were $2.0 billion, down $249 million from the corresponding 2013 period. Earnings decreased due to higher depreciation, operating and exploration expenses of $220 million, $140 million and $110 million, respectively, along with lower crude oil volumes of $90 million, partially offset by gains on asset sales of $200 million and higher natural gas realizations of $130 million.
The company’s average realization per barrel for U.S. crude oil and natural gas liquids in second quarter 2014 was $92.44, up from $92.25 a year ago. The average six-month realization per barrel for U.S. crude oil and natural gas liquids was $91.98 in 2014, compared to $93.36 a year earlier. The average natural gas realization in second quarter 2014 was $4.09 per thousand cubic feet, compared with $3.78 in 2013. The average six-month natural gas realizations were $4.42 per thousand cubic feet in 2014 and $3.44 in 2013.

29


Net oil-equivalent production of 667,000 barrels per day in second quarter 2014 was up 8,000 barrels per day, or 1 percent, from the second quarter a year earlier. Production increases in the Permian Basin in Texas and New Mexico and the Marcellus Shale in western Pennsylvania were partially offset by normal field declines. Net oil-equivalent production of 654,000 barrels per day in the first six months of 2014 was down 7,000 barrels per day, or 1 percent, from a year earlier. Production increases in the Permian Basin in Texas and New Mexico and the Marcellus Shale in western Pennsylvania were more than offset by normal field declines.
The net liquids component of oil-equivalent production of 460,000 barrels per day in second quarter 2014 was up 1 percent from the corresponding 2013 period. The net liquids component of oil-equivalent production of 449,000 barrels per day in the six-month period decreased 1 percent from the 2013 period. Net natural gas production was 1.24 billion cubic feet per day in second quarter 2014, an increase of 1 percent from the 2013 comparative period. Net natural gas production was 1.23 billion cubic feet per day in the six-month period, a decrease of 1 percent from the 2013 period.
 
Three Months Ended
June 30
 
Six Months Ended
June 30
 
2014
 
2013
 
2014
 
2013
 
(Millions of dollars)
     International Upstream Earnings*
$
4,210

 
$
3,866

 
$
7,605

 
$
8,650

     ____________________
 
 
 
 
 
 
 
      *  Includes foreign currency effects
$
(147
)
 
$
275

 
$