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EX-32.2 - EXHIBIT 32.2 - CHEVRON CORPa03312018ex322cfo-sox906.htm
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EX-31.2 - EXHIBIT 31.2 - CHEVRON CORPa03312018ex312cfo-sox302.htm
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EX-12.1 - EXHIBIT 12.1 - CHEVRON CORPa03312018ex121ratios.htm



 
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 March 31, 2018
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 No.)
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, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer  þ
 
Accelerated filer  o
Non-accelerated filer o (Do not check if a smaller reporting company)
 
 
Smaller reporting company o
 
Emerging growth company o
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o      
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).     Yes  o       No  þ
Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date:
Class
 
Outstanding as of March 31, 2018
Common stock, $.75 par value
 
1,910,956,734
 



TABLE OF CONTENTS
 
 
 
Page No.
 
PART I
FINANCIAL INFORMATION
Item 1.
 
 
Consolidated Statement of Income for the Three Months Ended March 31, 2018, and 2017
 
Consolidated Statement of Comprehensive Income for the Three Months Ended March 31, 2018, and 2017
 
Consolidated Balance Sheet at March 31, 2018, and December 31, 2017
 
Consolidated Statement of Cash Flows for the Three Months Ended March 31, 2018, and 2017
 
7-25
Item 2.
26-38
Item 3.
Item 4.
PART II
OTHER INFORMATION
Item 1.
Item 1A.
Item 2.
Item 5.
Other Information
Item 6.


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 or phrases such as “anticipates,” “expects,” “intends,” “plans,” “targets,” “forecasts,” “projects,” “believes,” “seeks,” “schedules,” “estimates,” “positions,” “pursues,” “may,” “could,” “should,” “budgets,” “outlook,” “trends,” “guidance,” “focus,” “on schedule,” “on track,” “is slated,” “goals,” “objectives,” “strategies,” “opportunities” 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; the company's ability to realize anticipated cost savings and expenditure reductions; 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 the company's suppliers, vendors, partners and equity affiliates, particularly during extended periods of low prices for crude oil and natural gas; 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 operations due to war, accidents, political events, civil unrest, severe weather, cyber threats and terrorist acts, crude oil production quotas or other actions that might be imposed by the Organization of Petroleum Exporting Countries, or other natural or human causes beyond the company's control; changing economic, regulatory and political environments in the various countries in which the company operates; general domestic and international economic and political conditions; the potential liability for remedial actions or assessments under existing or future environmental regulations and litigation; significant operational, investment or product changes required by existing or future environmental statutes and regulations, including international agreements and national or regional legislation and regulatory measures to limit or reduce greenhouse gas emissions; the potential liability resulting from other pending or future litigation; the company’s future acquisition or disposition of assets or shares or the delay or failure of such transactions to close based on required closing conditions; the potential for 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; material reductions in corporate liquidity and access to debt markets; the impact of the 2017 U.S. tax legislation on the company's future results; the effects of changed accounting rules under generally accepted accounting principles promulgated by rule-setting bodies; the company's ability to identify and mitigate the risks and hazards inherent in operating in the global energy industry; and the factors set forth under the heading “Risk Factors” on pages 19 through 22 of the company’s 2017 Annual Report on Form 10-K. 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
March 31
 
2018
 
2017
 
(Millions of dollars, except per-share amounts)
Revenues and Other Income
 
Sales and other operating revenues1
$
35,968

 
$
31,524

Income from equity affiliates
1,637

 
1,150

Other income
159

 
747

Total Revenues and Other Income
37,764

 
33,421

Costs and Other Deductions
 
 
 
Purchased crude oil and products
21,233

 
17,506

Operating expenses2
4,701

 
4,586

Selling, general and administrative expenses2
723

 
810

Exploration expenses
158

 
144

Depreciation, depletion and amortization
4,289

 
4,194

Taxes other than on income1
1,344

 
2,871

Interest and debt expense
159

 
51

Other components of net periodic benefit costs2
84

 
130

Total Costs and Other Deductions
32,691

 
30,292

Income Before Income Tax Expense
5,073

 
3,129

Income Tax Expense
1,414

 
430

Net Income
3,659

 
2,699

Less: Net income attributable to noncontrolling interests
21

 
17

Net Income Attributable to Chevron Corporation
$
3,638

 
$
2,682

Per Share of Common Stock:
 
 
 
Net Income Attributable to Chevron Corporation
 
 
 
— Basic
$
1.92

 
$
1.43

— Diluted
$
1.90

 
$
1.41

Dividends
$
1.12

 
$
1.08

Weighted Average Number of Shares Outstanding (000s)
 
 
 
— Basic
1,895,990

 
1,879,372

— Diluted
1,913,218

 
1,895,393

____________________
 
 
 
1 2017 includes excise, value-added and similar taxes of $1,677 million collected on behalf of third parties. Beginning in 2018, these taxes are netted in "Taxes other than on income" in accordance with ASU 2014-09. Refer to Note 17, "Revenue" beginning on page 24.
 
 
2 2017 adjusted to conform to ASU 2017-07. Refer to Note 5, "New Accounting Standards" on page 10.
 
 
 
See accompanying notes to consolidated financial statements.


3


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

 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Net Income
$
3,659

 
$
2,699

Currency translation adjustment
10

 
14

Unrealized holding (loss) gain on securities:
 
 
 
Net (loss) gain arising during period
(1
)
 
(5
)
Defined benefit plans:
 
 
 
Actuarial gain (loss):
 
 
 
Amortization to net income of net actuarial and settlement losses
157

 
171

Actuarial (loss) gain arising during period
(1
)
 
(14
)
Prior service cost:
 
 
 
Amortization to net income of net prior service costs
(4
)
 
(5
)
Defined benefit plans sponsored by equity affiliates
8

 
6

Income tax expense on defined benefit plans
(39
)
 
(50
)
Total
121

 
108

Other Comprehensive Gain, Net of Tax
130

 
117

Comprehensive Income
3,789

 
2,816

Comprehensive income attributable to noncontrolling interests
(21
)
 
(17
)
Comprehensive Income Attributable to Chevron Corporation
$
3,768

 
$
2,799









See accompanying notes to consolidated financial statements.


4


CHEVRON CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Unaudited)
 
 
At March 31
2018
 
At December 31
2017
 
 
(Millions of dollars)
ASSETS
 
 
Cash and cash equivalents
 
$
6,466

 
$
4,813

Marketable securities
 
38

 
9

Accounts and notes receivable, net
 
15,771

 
15,353

Inventories
 
 
 
 
Crude oil and petroleum products
 
3,705

 
3,142

Chemicals
 
475

 
476

Materials, supplies and other
 
1,948

 
1,967

Total inventories
 
6,128

 
5,585

Prepaid expenses and other current assets 
 
3,323

 
2,800

Total Current Assets
 
31,726

 
28,560

Long-term receivables, net
 
2,723

 
2,849

Investments and advances
 
33,470

 
32,497

Properties, plant and equipment, at cost
 
344,977

 
344,485

Less: Accumulated depreciation, depletion and amortization
 
169,131

 
166,773

Properties, plant and equipment, net
 
175,846

 
177,712

Deferred charges and other assets 
 
6,946

 
7,017

Goodwill
 
4,531

 
4,531

Assets held for sale
 
1,200

 
640

Total Assets
 
$
256,442

 
$
253,806

LIABILITIES AND EQUITY
 
 
Short-term debt 
 
$
8,601

 
$
5,192

Accounts payable
 
14,479

 
14,565

Accrued liabilities
 
4,587

 
5,267

Federal and other taxes on income 
 
1,867

 
1,600

Other taxes payable
 
1,096

 
1,113

Total Current Liabilities
 
30,630

 
27,737

Long-term debt 
 
31,054

 
33,477

Capital lease obligations
 
90

 
94

Deferred credits and other noncurrent obligations
 
20,674

 
21,106

Noncurrent deferred income taxes 
 
15,082

 
14,652

Noncurrent employee benefit plans
 
7,346

 
7,421

Total Liabilities*
 
104,876

 
104,487

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 March 31, 2018, and December 31, 2017)
 
1,832

 
1,832

Capital in excess of par value
 
16,963

 
16,848

Retained earnings
 
175,619

 
174,106

Accumulated other comprehensive loss
 
(3,459
)
 
(3,589
)
Deferred compensation and benefit plan trust
 
(240
)
 
(240
)
Treasury stock, at cost (531,719,846 and 537,974,695 shares at March 31, 2018, and December 31, 2017, respectively)
 
(40,359
)
 
(40,833
)
Total Chevron Corporation Stockholders’ Equity
 
150,356

 
148,124

Noncontrolling interests
 
1,210

 
1,195

Total Equity
 
151,566

 
149,319

Total Liabilities and Equity
 
$
256,442

 
$
253,806

____________________
 
 
 
 
* Refer to Note 14, "Other Contingencies and Commitments" beginning on page 20.

See accompanying notes to consolidated financial statements.


5


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

 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Operating Activities
 
 
 
Net Income
$
3,659

 
$
2,699

Adjustments
 
 
 
Depreciation, depletion and amortization
4,289

 
4,194

Dry hole expense
45

 
7

Distributions less than income from equity affiliates 1
(998
)
 
(658
)
Net before-tax gains on asset retirements and sales
(12
)
 
(764
)
Net foreign currency effects
63

 
131

Deferred income tax provision
383

 
(563
)
Net increase in operating working capital 2
(2,104
)
 
(1,052
)
Decrease in long-term receivables
128

 
20

Net increase in other deferred charges 2
(12
)
 
(33
)
Cash contributions to employee pension plans
(149
)
 
(170
)
Other
(249
)
 
(34
)
Net Cash Provided by Operating Activities 1, 2
5,043

 
3,777

Investing Activities
 
 
 
Capital expenditures
(2,997
)
 
(3,315
)
Proceeds and deposits related to asset sales and returns of investment 1, 2
111

 
1,846

Net (purchases) sales of marketable securities
(29
)
 
2

Net repayment (borrowing) of loans by equity affiliates
26

 
(6
)
Net Cash Used for Investing Activities 1, 2
(2,889
)
 
(1,473
)
Financing Activities
 
 
 
Net borrowings (repayments) of short-term obligations
3,214

 
(3,928
)
Proceeds from issuance of long-term debt
73

 
3,994

Repayments of long-term debt and other financing obligations
(2,331
)
 
(966
)
Cash dividends — common stock
(2,124
)
 
(2,029
)
Distributions to noncontrolling interests
(11
)
 

Net sales of treasury shares
566

 
245

Net Cash Used for Financing Activities
(613
)
 
(2,684
)
Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash 2
33

 
39

Net Change in Cash, Cash Equivalents and Restricted Cash 2
1,574

 
(341
)
Cash, Cash Equivalents and Restricted Cash at January 1 2
5,943

 
8,414

Cash, Cash Equivalents and Restricted Cash at March 31 2
$
7,517

 
$
8,073

____________________
 
 
 
1   2017 adjusted to conform to Accounting Standards Update 2016-15. Refer to Note 4, "Information Relating to the Consolidated Statement of Cash Flows" beginning on page 8.
2   2017 adjusted to conform to Accounting Standards Update 2016-18. Refer to Note 4, "Information Relating to the Consolidated Statement of Cash Flows" beginning on page 8.


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-month period ended March 31, 2018, 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 2017 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 three months ending March 31, 2018, are reflected in the table below.
Changes in Accumulated Other Comprehensive Income (Loss) by Component (1) 
 
 
Three Months Ended March 31, 2018
 
 
Currency Translation Adjustment
 
Unrealized Holding Gains (Losses) on Securities
 
Derivatives
 
Defined Benefit Plans
 
Total
 
 
(Millions of dollars)
Balance at January 1
 
$
(105
)
 
$
(5
)
 
$
(2
)
 
$
(3,477
)
 
$
(3,589
)
Components of Other Comprehensive Income (Loss):
 
 
 
 
 
 
 
 
Before Reclassifications
 
10

 
(1
)
 

 
5

 
14

Reclassifications (2)
 

 

 

 
116

 
116

Net Other Comprehensive Income (Loss)
 
10

 
(1
)
 

 
121

 
130

Balance at March 31
 
$
(95
)
 
$
(6
)
 
$
(2
)
 
$
(3,356
)
 
$
(3,459
)
________________________________
(1) All amounts are net of tax.
(2) Refer to Note 10, Employee Benefits for reclassified components totaling $153 million that are included in employee benefit costs for the three months ending March 31, 2018. Related income taxes for the same period, totaling $37 million, are reflected in "Income Tax Expense" on the Consolidated Statement of Income. All other reclassified amounts were insignificant.
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 three months of 2018 and 2017 is as follows:
 
2018
 
2017
 
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
$
148,124

 
$
1,195

 
$
149,319

 
$
145,556

 
$
1,166

 
$
146,722

Net income
3,638

 
21

 
3,659

 
2,682

 
17

 
2,699

Dividends
(2,124
)
 

 
(2,124
)
 
(2,030
)
 

 
(2,030
)
Distributions to noncontrolling interests

 
(11
)
 
(11
)
 

 

 

Treasury shares, net
474

 

 
474

 
231

 

 
231

Other changes, net*
244

 
5

 
249

 
153

 
15

 
168

Balance at March 31
$
150,356

 
$
1,210

 
$
151,566

 
$
146,592

 
$
1,198

 
$
147,790

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


7

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


Note 4. Information Relating to the Consolidated Statement of Cash Flows
The “Net increase in operating working capital” was composed of the following operating changes:
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
(Increase) decrease in accounts and notes receivable
$
(335
)
 
$
317

Increase in inventories
(543
)
 
(550
)
(Increase) decrease in prepaid expenses and other current assets 1
(608
)
 
26

Decrease in accounts payable and accrued liabilities 1
(807
)
 
(1,090
)
Increase in income and other taxes payable
189

 
245

Net increase in operating working capital 1
$
(2,104
)
 
$
(1,052
)
____________________
 
 
 
1   2017 adjusted to conform to Accounting Standards Update 2016-18.
“Net Cash Provided by Operating Activities” included the following cash payments for interest on debt and for income taxes:
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Interest on debt (net of capitalized interest)
$
105

 
$

Income taxes
843

 
494

"Other" includes changes in postretirement benefits obligations and other long-term liabilities.
The “Net (purchases) sales of marketable securities” consisted of the following gross amounts:
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Marketable securities purchased
$
(29
)
 
$

Marketable securities sold

 
2

Net (purchases) sales of marketable securities
$
(29
)
 
$
2

The “Net repayment (borrowing) of loans by equity affiliates” consisted of the following gross amounts:
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Borrowing of loans by equity affiliates
$

 
$
(70
)
Repayment of loans by equity affiliates
26

 
64

Net repayment (borrowing) of loans by equity affiliates
$
26

 
$
(6
)


8

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


The “Net borrowings (repayments) of short-term obligations" consisted of the following gross and net amounts:
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Repayments of short-term obligations
$
(1,377
)
 
$
(2,952
)
Proceeds from issuances of short-term obligations
658

 
3,415

Net borrowings of short-term obligations with three months or less maturity
3,933

 
(4,391
)
Net borrowings (repayments) of short-term obligations
$
3,214

 
$
(3,928
)
The “Net sales of treasury shares” represents the value of shares sold for share-based compensation plans, net of purchases. Purchases totaled $1 million for the first three months in 2018 and $1 million for the first three months in 2017. No purchases were made under the company's share repurchase program in the first three months of 2018 or 2017.
The major components of “Capital expenditures” and the reconciliation of this amount to the capital and exploratory expenditures, including equity affiliates, are as follows:
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Additions to properties, plant and equipment
$
2,937

 
$
3,305

Additions to investments
15

 
3

Current year dry hole expenditures
45

 
7

 Capital expenditures
2,997

 
3,315

Expensed exploration expenditures
113

 
137

Assets acquired through capital lease obligations

 
1

 Capital and exploratory expenditures, excluding equity affiliates
3,110

 
3,453

Company’s share of expenditures by equity affiliates
1,295

 
939

 Capital and exploratory expenditures, including equity affiliates
$
4,405

 
$
4,392


On January 1, 2018, Chevron adopted Accounting Standards Updates (ASU) 2016-15 and 2016-18, which require retrospective adjustment of prior periods in the Statement of Cash Flows.
In addition to other requirements, ASU 2016-15 specifies new standards for the classification of distributions from equity affiliates. In adopting these new standards, Chevron utilized the cumulative earnings approach to evaluate returns on and returns of investment from equity affiliates. For the first three months of 2017, a total of $6 million was reclassified from “Distributions less than income from equity affiliates” to “Proceeds and deposits related to asset sales and returns of investment.”
Adoption of ASU 2016-18 requires the inclusion of restricted cash and associated changes in restricted cash in the Consolidated Statement of Cash Flows. The impact of ASU 2016-18 is captured across several line items in the Statement of Cash Flows, including “Net decrease (increase) in operating working capital,” “Decrease (increase) in other deferred charges,” and “Proceeds and deposits related to asset sales and returns of investment” with associated net changes captured in both “Net Cash Provided by Operating Activities” and “Net Cash Used for Investing Activities.” The line item “Net sales (purchases) of other short-term investments” was removed in conjunction with the adoption of ASU 2016-18.
The table on the next page quantifies the beginning and ending balances of restricted cash and restricted cash equivalents in the Consolidated Balance Sheet:



9

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


 
 
At March 31
 
At December 31
 
 
2018
 
2017
 
2017
 
2016
 
 
(Millions of dollars)
 
(Millions of dollars)
Cash and Cash Equivalents
 
$
6,466

 
$
6,983

 
$
4,813

 
$
6,988

Restricted cash included in "Prepaid expenses and other current assets"
 
316

 
306

 
405

 
488

Restricted cash included in "Deferred charges and other assets"
 
735

 
784

 
725

 
938

Total Cash, Cash Equivalents and Restricted Cash
 
$
7,517

 
$
8,073

 
$
5,943

 
$
8,414

 
 
 
 
 
 
 
 
 
Additional information related to "Restricted Cash" is included on page 22 in Note 15 under the heading "Restricted Cash."
Note 5. New Accounting Standards
Revenue Recognition (Topic 606): Revenue from Contracts with Customers On January 1, 2018, Chevron adopted ASU 2014-09 and its related amendments using the modified retrospective transition method, which did not require the restatement of prior periods. The impact of the adoption of the standard did not have a material effect on the company’s consolidated financial statements. For additional information on the company’s revenue, refer to Note 17 beginning on page 24.
Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments Effective January 1, 2018, Chevron adopted ASU 2016-15 on a retrospective basis. The standard provides clarification on how certain cash receipts and cash payments are presented and classified on the statement of cash flows. The adoption of this ASU did not have a material impact on the company's Consolidated Statement of Cash Flows. For additional information, refer to Note 4 beginning on page 8.
Statement of Cash Flows (Topic 230): Restricted Cash Effective January 1, 2018, Chevron adopted ASU 2016-18 on a retrospective basis. The standard requires an entity to explain the changes in the total of cash, cash equivalents, restricted cash and restricted cash equivalents on the statement of cash flows and to provide a reconciliation to the balance sheet when the cash, cash equivalents, restricted cash and restricted cash equivalents are not separately presented or are presented in more than one line item on the balance sheet. The company’s restricted cash balances are now included in the beginning and ending balances on the Consolidated Statement of Cash Flows. For additional information, refer to Note 4 beginning on page 8.
Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20) On January 1, 2018, the company adopted ASU 2017-05 which provides clarification regarding the guidance on accounting for the derecognition of nonfinancial assets. The adoption of the standard had no impact on the company’s consolidated financial statements.
Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost Effective January 1, 2018, Chevron adopted ASU 2017-07 on a retrospective basis. The standard requires the disaggregation of the service cost component from the other components of net periodic benefit cost and allows only the service cost component of net benefit cost to be eligible for capitalization. The effects of retrospective adoption on the Consolidated Statement of Income for the period ended March 31, 2017 were to move $70 million from "Operating expenses" and $60 million from "Selling, general and administrative expenses" to "Other components of net periodic benefits cost."
Leases (Topic 842) In February 2016, the FASB issued ASU 2016-02 which becomes effective for the company January 1, 2019. The standard requires that lessees present right-of-use assets and lease liabilities on the balance sheet. The company is evaluating the effect of the standard on its consolidated financial statements.
Income Statement - Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income In February 2018, the FASB issued ASU 2018-02, which becomes effective for the company January 1, 2019.  The standard permits companies to reclassify the tax effects stranded in accumulated other comprehensive income as a result of tax reform to retained earnings and also requires


10

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


additional new disclosures.  The company is evaluating the effect of the standard on its consolidated financial statements.
Financial Instruments - Credit Losses (Topic 326) In June 2016, the FASB issued ASU 2016-13, which becomes effective for the company beginning January 1, 2020. The standard requires companies to use forward-looking information to calculate credit loss estimates. The company is evaluating the effect of the standard on its consolidated financial statements.

Note 6. 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 plant. 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 worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities and technology companies.
The company’s segments are managed by “segment managers” who report to the “chief operating decision maker” (CODM). The 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.
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).


11

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-month periods ended March 31, 2018 and 2017, are presented in the following table:
 
Three Months Ended
March 31
Segment Earnings
2018
 
2017
 
(Millions of dollars)
Upstream
 
 
 
United States
$
648

 
$
80

International
2,704

 
1,437

Total Upstream
3,352

 
1,517

Downstream
 
 
 
United States
442

 
469

International
286

 
457

Total Downstream
728

 
926

Total Segment Earnings
4,080

 
2,443

All Other
 
 
 
Interest expense
(149
)
 
(43
)
Interest income
19

 
15

Other
(312
)
 
267

Net Income Attributable to Chevron Corporation
$
3,638

 
$
2,682

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; technology companies; and assets of the corporate administrative functions. Segment assets at March 31, 2018, and December 31, 2017, are as follows: 
Segment Assets
At March 31
2018
 
At December 31
2017
 
(Millions of dollars)
Upstream
 
 
 
United States
$
41,791

 
$
40,770

International
159,071

 
159,612

Goodwill
4,531

 
4,531

Total Upstream
205,393

 
204,913

Downstream
 
 
 
United States
23,862

 
23,202

International
17,200

 
17,434

Total Downstream
41,062

 
40,636

Total Segment Assets
246,455

 
245,549

All Other
 
 
 
United States
5,682

 
4,938

International
4,305

 
3,319

Total All Other
9,987

 
8,257

Total Assets — United States
71,335

 
68,910

Total Assets — International
180,576

 
180,365

Goodwill
4,531

 
4,531

Total Assets
$
256,442

 
$
253,806



12

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


Segment Sales and Other Operating Revenues Segment sales and other operating revenues, including internal transfers, for the three-month periods ended March 31, 2018 and 2017, 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 insurance operations, real estate activities and technology companies.
 
Three Months Ended
March 31
 Sales and Other Operating Revenues
2018
 
2017
 
(Millions of dollars)
Upstream
 
 
 
United States
$
4,577

 
$
3,240

International
8,656

 
6,581

Subtotal
13,233

 
9,821

Intersegment Elimination — United States
(2,757
)
 
(2,241
)
Intersegment Elimination — International
(3,215
)
 
(2,720
)
Total Upstream
7,261

 
4,860

Downstream *
 
 
 
United States
13,042

 
12,432

International
15,935

 
14,513

Subtotal
28,977

 
26,945

Intersegment Elimination — United States
(3
)
 
(3
)
Intersegment Elimination — International
(328
)
 
(330
)
Total Downstream
28,646

 
26,612

All Other
 
 
 
United States
227

 
235

International
3

 
5

Subtotal
230

 
240

Intersegment Elimination — United States
(166
)
 
(183
)
Intersegment Elimination — International
(3
)
 
(5
)
Total All Other
61

 
52

Sales and Other Operating Revenues
 
 
 
United States
17,846

 
15,907

International
24,594

 
21,099

Subtotal
42,440

 
37,006

Intersegment Elimination — United States
(2,926
)
 
(2,427
)
Intersegment Elimination — International
(3,546
)
 
(3,055
)
Total Sales and Other Operating Revenues
$
35,968

 
$
31,524

_____________________________
 
 
 
* 2017 includes excise, value-added and similar taxes of $1,677 million collected on behalf of third parties. Beginning in 2018, these taxes are netted in "Taxes other than on income" in accordance with ASU 2014-09. Refer to Note 17, "Revenue" beginning on page 24.
Note 7. 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.


13

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


The summarized financial information for CUSA and its consolidated subsidiaries is as follows:

Three Months Ended
March 31

2018
 
2017
 
(Millions of dollars)
Sales and other operating revenues*
$
28,058

 
$
24,408

Costs and other deductions*
27,596

 
24,099

Net income attributable to CUSA
697

 
421

_____________________________

 
 
 
* 2017 includes excise, value-added and similar taxes collected on behalf of third parties of $1,207 million. Beginning in
  2018, these taxes are netted in "Taxes other than on income" in accordance with ASU 2014-09.
 
At March 31
2018
 
At December 31
2017
 
(Millions of dollars)
Current assets
$
13,406

 
$
12,163

Other assets
55,482

 
54,994

Current liabilities
17,606

 
17,379

Other liabilities
12,623

 
12,541

Total CUSA net equity
$
38,659

 
$
37,237

Memo: Total debt
$
3,050

 
$
3,056

Note 8. Summarized Financial Data — Tengizchevroil LLP
Chevron has a 50 percent equity ownership interest in Tengizchevroil LLP (TCO). Summarized financial information for 100 percent of TCO is presented in the following table:
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Sales and other operating revenues
$
4,325

 
$
3,395

Costs and other deductions
1,942

 
1,754

Net income attributable to TCO
1,679

 
1,158

Note 9. Summarized Financial Data — Chevron Phillips Chemical Company LLC
Chevron has a 50 percent equity ownership interest in Chevron Phillips Chemical Company LLC (CPChem). Summarized financial information for 100 percent of CPChem is presented in the table below:
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Sales and other operating revenues
$
2,577

 
$
2,445

Costs and other deductions
2,151

 
2,019

Net income attributable to CPChem
585

 
503



14

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


Note 10. 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. The increase to the pre-Medicare 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.
The components of net periodic benefit costs for 2018 and 2017 are as follows:
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Pension Benefits
 
 
 
United States
 
 
 
Service cost
$
120

 
$
122

Interest cost
92

 
91

Expected return on plan assets
(159
)
 
(149
)
Amortization of prior service credits
1

 
(1
)
Amortization of actuarial losses
76

 
85

Settlement losses
66

 
78

Total United States
196

 
226

International
 
 
 
Service cost
40

 
37

Interest cost
46

 
53

Expected return on plan assets
(66
)
 
(58
)
Amortization of prior service costs
2

 
3

Amortization of actuarial losses
11

 
9

Settlement losses

 

Total International
33

 
44

Net Periodic Pension Benefit Costs
$
229

 
$
270

Other Benefits*
 
 
 
Service cost
$
13

 
$
8

Interest cost
21

 
23

Amortization of prior service costs
(7
)
 
(7
)
Amortization of actuarial losses
4

 
(1
)
Net Periodic Other Benefit Costs
$
31

 
$
23

___________________________________
* 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.
Through March 31, 2018, a total of $149 million was contributed to employee pension plans (including $91 million to the U.S. plans). Total contributions for the full year are currently estimated to be $950 million ($700 million for the U.S. plans and $250 million for the international plans). Actual contribution amounts are dependent upon plan investment returns, changes in pension obligations, regulatory requirements and other economic factors. Additional funding may ultimately be required if investment returns are insufficient to offset increases in plan obligations.
During the first three months of 2018, the company contributed $45 million to its OPEB plans. The company anticipates contributing approximately $129 million during the remainder of 2018.


15

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


Note 11. Income Taxes
The 2018 increase in income tax expense between periods of $984 million, from $430 million in 2017 to $1.41 billion in 2018, is a result of the year-over-year increase in total income before income tax expense, which is primarily due to effects of higher crude oil prices and production. The company’s effective tax rate changed between periods from 14 percent in 2017 to 28 percent in 2018. The change in effective tax rate is primarily a consequence of the mix effect resulting from the absolute level of earnings or losses and whether they arose in higher or lower tax rate jurisdictions.
U.S. tax reform resulted in the remeasurement of U.S. deferred tax assets and liabilities in 2017. The final
impact will be determined as the actual 2017 U.S. tax return is prepared and completed later in 2018, and this may result in a change to the provisional amounts that were recognized in 2017.
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 March 31, 2018. For these jurisdictions, the latest years for which income tax examinations had been finalized were as follows: United States — 2011, Nigeria — 2000, Australia — 2006 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 12. Assets Held For Sale
At March 31, 2018, the company classified $1.20 billion of net properties, plant and equipment as “Assets held for sale” on the Consolidated Balance Sheet. These assets are primarily associated with upstream and downstream operations that are anticipated to be sold in the next 12 months. The revenues and earnings contributions of these assets in 2017 and the first three months of 2018 were not material.
Note 13. 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 eight 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
Background 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


16

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


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.
Lago Agrio Judgment In 2008, a mining engineer appointed by the court to identify and determine the cause of environmental damage, and to specify steps needed to remediate it, issued a report recommending that the court assess $18.9 billion, which would, according to the engineer, provide financial compensation for purported damages, including wrongful death claims, and pay for, among other items, environmental remediation, health care systems and additional infrastructure for Petroecuador. The engineer’s report also asserted that an additional $8.4 billion could be assessed against Chevron for unjust enrichment. In 2009, following the disclosure by Chevron of evidence that the judge participated in meetings in which businesspeople and individuals holding themselves out as government officials discussed the case and its likely outcome, the judge presiding over the case was recused. In 2010, Chevron moved to strike the mining engineer’s report and to dismiss the case based on evidence obtained through discovery in the United States indicating that the report was prepared by consultants for the plaintiffs before being presented as the mining engineer’s independent and impartial work and showing further evidence of misconduct. In August 2010, the judge issued an order stating that he was not bound by the mining engineer’s report and requiring the parties to provide their positions on damages within 45 days. Chevron subsequently petitioned for recusal of the judge, claiming that he had disregarded evidence of fraud and misconduct and that he had failed to rule on a number of motions within the statutory time requirement.
In September 2010, Chevron submitted its position on damages, asserting that no amount should be assessed against it. The plaintiffs’ submission, which relied in part on the mining engineer’s report, took the position that damages are between approximately $16 billion and $76 billion and that unjust enrichment should be assessed in an amount between approximately $5 billion and $38 billion. The next day, the judge issued an order closing the evidentiary phase of the case and notifying the parties that he had requested the case file so that he could prepare a judgment. Chevron petitioned to have that order declared a nullity in light of Chevron’s prior recusal petition, and because procedural and evidentiary matters 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


17

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


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. The reporting justice of the Constitutional Court heard oral arguments on the appeal on July 16, 2015.
Lago Agrio Plaintiffs' Enforcement Actions 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 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 and, 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 to the Supreme Court of Canada and, on September 4, 2015, the Supreme Court dismissed the appeal and affirmed that the Ontario Superior Court of Justice has jurisdiction over Chevron and Chevron Canada Limited for purposes of the action. The recognition and enforcement proceeding and related preliminary motions are proceeding in the Ontario Superior Court of Justice. On January 20, 2017, the Ontario Superior Court of Justice granted Chevron Canada Limited’s and Chevron Corporation’s motions for summary judgment, concluding that the two companies are separate legal entities with separate rights and obligations. As a result, the Superior Court dismissed the recognition and enforcement claim against Chevron Canada Limited.  Chevron Corporation still remains as a defendant in the action. On February 3, 2017, the Lago Agrio plaintiffs appealed the Superior Court's January 20, 2017 decision.
On June 27, 2012, the Lago Agrio plaintiffs filed a complaint against Chevron Corporation in the Superior Court of Justice in Brasilia, Brazil, seeking to recognize and enforce the Ecuadorian judgment. Chevron has answered the complaint. In accordance with Brazilian procedure, the matter was referred to the public prosecutor for a nonbinding opinion of the issues raised in the complaint. On May 13, 2015, the public prosecutor issued its nonbinding opinion and recommended that the Superior Court of Justice reject the plaintiffs’ recognition and enforcement request, finding, among other things, that the Lago Agrio judgment was procured through fraud and corruption and cannot be recognized in Brazil because it violates Brazilian and international public order. On November 29, 2017, the Superior Court of Justice issued a decision dismissing the Lago Agrio plaintiffs’ recognition and enforcement proceeding based on jurisdictional grounds.
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 14, 2012, the Argentinean court rejected a motion to revoke the Freeze Order but modified


18

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


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 to which the Lago Agrio plaintiffs responded on December 29, 2015. On April 19, 2016, the public prosecutor in Argentina issued a non-binding opinion recommending to the National Court, First Instance, of Argentina that it reject the Lago Agrio plaintiffs' request to recognize the Ecuadorian judgment in Argentina. On February 24, 2017, the public prosecutor in Argentina issued a supplemental opinion reaffirming its previous recommendations. On November 1, 2017, the National Court, First Instance, of Argentina issued a decision dismissing the Lago Agrio plaintiffs' recognition and enforcement proceeding based on jurisdictional grounds. On November 2, 2017, the Lago Agrio plaintiffs appealed this decision to the Federal Civil Court of Appeals.
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.
Company's Bilateral Investment Treaty Arbitration Claims 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 January 25, 2012, the Tribunal issued its First Interim Measures Award 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 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. On February 27, 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 Republic of Ecuador subsequently filed in the District Court of the Hague a request to set aside the Tribunal’s Interim Awards and the First Partial Award (described below), and on January 20, 2016, the District Court denied the Republic's request. On April 13, 2016, the Republic of Ecuador appealed the decision. On July 18, 2017, the Appeals Court of the Hague denied the Republic's appeal. On October 18, 2017, the Republic appealed the decision of the Appeals Court of the Hague to the Supreme Court of the Netherlands.
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. The Tribunal held a hearing on April 29-30, 2014, to address remaining issues relating to Phase One, and on March 12, 2015, it issued a nonbinding decision that the Lago Agrio plaintiffs' complaint, on its face, includes claims not barred by the settlement agreement between the Republic of Ecuador and Texpet. In the same decision, the Tribunal deferred


19

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


to Phase Two remaining issues from Phase One, including whether the Republic of Ecuador breached the 1995 settlement agreement and the remedies that are available to Chevron and Texpet as a result of that breach. Phase Two issues were addressed at a hearing held in April and May 2015. The Tribunal has not set a date for Phase Three, the damages phase of the arbitration.
Company's RICO Action 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 sought relief that included 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. 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 appealed the Federal District Court's decision, and, on April 20, 2015, a panel of the U.S. Court of Appeals for the Second Circuit heard oral arguments. On August 8, 2016, the Second Circuit issued a unanimous opinion affirming in full the judgment of the Federal District Court in favor of Chevron. On October 27, 2016, the Second Circuit denied the defendants' petitions for en banc rehearing of the opinion on their appeal. On March 27, 2017, two of the defendants filed a petition for a Writ of Certiorari to the United States Supreme Court. On June 19, 2017, the United States Supreme Court denied the defendants' petition for a Writ of Certiorari.
Management's Assessment 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 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 14. 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 11 on page 16 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 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.


20

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


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 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 Governmental entities in California and other jurisdictions have filed legal proceedings against fossil fuel producing companies, including Chevron, purporting to seek legal and equitable relief to address alleged impacts of climate change. Further such proceedings are likely to be filed by other parties. The unprecedented legal theories set forth in these proceedings entail the possibility of damages liability and injunctions against the production of all fossil fuels that, while we believe remote, could have a material adverse effect on the Company’s results of operations and financial condition. Management believes that these proceedings are legally and factually meritless and detract from constructive efforts to address the important policy issues presented by climate change, and will vigorously defend against such proceedings.
Chevron receives claims from and submits claims to customers; trading partners; joint venture partners; U.S. federal, state and local regulatory bodies; governments; contractors; insurers; suppliers; and individuals. 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 significant gains or losses in future periods.
Note 15. 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


21

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


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.
The fair value hierarchy for assets and liabilities measured at fair value on a recurring basis at March 31, 2018, and December 31, 2017, is as follows:
Assets and Liabilities Measured at Fair Value on a Recurring Basis
(Millions of dollars)
 
At March 31, 2018
 
At December 31, 2017
 
Total
 
Level 1
 
Level 2
 
Level 3
 
Total
 
Level 1
 
Level 2
 
Level 3
Marketable Securities
$
38

 
$
38

 
$

 
$

 
$
9

 
$
9

 
$

 
$

Derivatives
7

 

 
7

 

 
22

 

 
22

 

Total Assets at Fair Value
$
45

 
$
38

 
$
7

 
$

 
$
31

 
$
9

 
$
22

 
$

Derivatives
95

 
64

 
31

 

 
124

 
78

 
46

 

Total Liabilities at Fair Value
$
95

 
$
64

 
$
31

 
$

 
$
124

 
$
78

 
$
46

 
$

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 March 31, 2018.
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 March 31, 2018, and December 31, 2017, are as follows:
Cash and Cash Equivalents The company holds cash equivalents 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 $6.5 billion and $4.8 billion at March 31, 2018, and December 31, 2017, respectively. The fair values of cash and cash equivalents are classified as Level 1 and reflect the cash that would have been received if the instruments were settled at March 31, 2018.
Restricted Cash had a carrying/fair value of $1.1 billion and $1.1 billion at March 31, 2018, and December 31, 2017, respectively. At March 31, 2018, restricted cash is classified as Level 1 and includes restricted funds related to certain upstream abandonment activities, tax payments and refundable deposits related to pending asset sales, which are reported in "Prepaid expenses and other current assets" and “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 $21.1 billion and $23.5 billion at March 31, 2018, and December 31, 2017, respectively. The fair value of long-term debt at March 31, 2018, and December 31, 2017 was $21.1 billion and $23.9 billion, respectively. Long-term debt primarily includes corporate issued bonds. The fair value of corporate bonds classified as Level 1 is $20.4 billion. The fair value of other long-term debt classified as Level 2 is $0.7 billion.
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 March 31, 2018, and December 31, 2017, 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 March 31, 2018, is as follows:
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
(Millions of dollars)
 
At March 31, 2018
 
 
 
 
 
 
 
 
 
 
 
 
Total
 
Level 1
 
Level 2
 
Level 3
 
Before-Tax Loss
 
 
 
 
 
 
 
 Properties, plant and equipment, net (held and used)
$

 
$

 
$

 
$

 
$

 
 Properties, plant and equipment, net (held for sale)
631

 

 
631

 

 
163

 
 Investments and advances
1

 

 

 
1

 
1

 
 Total Assets at Fair Value
$
632

 
$

 
$
631

 
$
1

 
$
164

 
Properties, plant and equipment The company did not have any individually material impairments of long-lived assets measured at fair value on a nonrecurring basis to report in first quarter 2018.
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 first quarter 2018.
Note 16. 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 March 31, 2018, and December 31, 2017, 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 March 31
2018
 
At December 31
2017
Commodity
 
Accounts and notes receivable, net
 
$
7

 
$
22

Commodity
 
Long-term receivables, net
 

 

Total Assets at Fair Value
 
$
7

 
$
22

Commodity
 
Accounts payable
 
$
90

 
$
122

Commodity
 
Deferred credits and other noncurrent obligations
 
5

 
2

Total Liabilities at Fair Value
 
$
95

 
$
124




23

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


Consolidated Statement of Income: The Effect of Derivatives Not Designated as Hedging Instruments
(Millions of dollars)
 
 
 
 
(Loss) / Gain
Three Months Ended
March 31
Type of
Contract
 
Statement of Income Classification
 
2018
 
2017
Commodity
 
Sales and other operating revenues
 
$
(12
)
 
$
162

Commodity
 
Purchased crude oil and products
 
(9
)
 
4

Commodity
 
Other income
 

 
(2
)
 
 
 
 
$
(21
)
 
$
164

The table below represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at March 31, 2018, and December 31, 2017.
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 March 31, 2018
 
 
 
 
 
Derivative Assets
 
$
1,180

 
$
1,173

 
$
7

 
$

 
$
7

Derivative Liabilities
 
$
1,268

 
$
1,173

 
$
95

 
$

 
$
95

 
 
 
 
 
 
 
 
 
 
 
At December 31, 2017
 
 
 
 
 
 
 
 
 
 
Derivative Assets
 
$
1,169

 
$
1,147

 
$
22

 
$

 
$
22

Derivative Liabilities
 
$
1,271

 
$
1,147

 
$
124

 
$

 
$
124

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 17. Revenue
On January 1, 2018, Chevron adopted ASU 2014-09, Revenue from Contracts with Customers (ASC 606), and its related amendments using the modified retrospective transition method, which did not require the restatement of prior periods. The adoption did not result in a material change in the company’s accounting or have a material effect on the company’s financial position, including the measurement of revenue, the timing of revenue recognition and the recognition of contract assets, liabilities and related costs.
The most significant change is the presentation of excise, value-added and similar taxes collected on behalf of third parties, which are no longer presented within “Sales and other operating revenue” on the Consolidated Statement of Income starting in 2018. These taxes, which totaled $1.9 billion in the three months ended March 31, 2018, are now netted in “Taxes other than on income” in the Consolidated Statement of Income. This change to presentation had no impact on earnings. In the three months ended March 31, 2017, these taxes totaled $1.7 billion.
Under the new standard, the company accounts for commodity delivery orders as separate performance obligations. Revenue is recognized when the performance obligation is satisfied, which continues to typically occur at the point in time when control of the product transfers to the customer. Payment is generally due within 30 days from delivery. The company has elected to account for delivery transportation as a fulfillment cost, not a separate performance obligation. These costs continue to be recognized as an operating expense in the period when revenue for the related commodity is recognized.
Revenue is measured as the amount the company expects to receive in exchange for transferring commodities to the customer. The company’s commodity sales are typically based on prevailing market-based prices and may


24

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)


include discounts and allowances. Until market prices become known under terms of the company’s contracts, the transaction price included in revenue is based on the company’s estimate of the most likely outcome.
Discounts and allowances are estimated using a combination of historical and recent data trends. When deliveries contain multiple products, an observable standalone selling price is generally used to measure revenue for each product. The company includes estimates in the transaction price only to the extent that a significant reversal of revenue is not probable in subsequent periods.
The company applied the optional exemption to not report any unfulfilled performance obligations related to contracts that have terms of less than one year. The amount of future revenue for unfulfilled performance obligations under long-term contracts with fixed components was insignificant for the three months ended March 31, 2018.
Revenue from contracts with customers is presented in “Sales and other operating revenue” along with some activity that is accounted for outside the scope of ASC 606, which is not material to this line, on the Consolidated Statement of Income. Purchases and sales of inventory with the same counterparty that are entered into in contemplation of one another (including buy/sell arrangements) are combined and recorded on a net basis and reported in “purchased crude oil and products” on the Consolidated Statement of Income. Refer to Note 6 - Operating Segments and Geographical Data beginning on page 11 for additional information on the company’s segmentation of revenue.
Receivables related to revenue from contracts with customers are included in “Accounts and notes receivable, net” on the Consolidated Balance Sheet, net of the allowance for doubtful accounts. The net balance of these receivables was $9.8 billion and $10.5 billion at January 1, 2018 and March 31, 2018, respectively. Other items included in “Accounts and notes receivable, net” represent amounts due from partners for their share of joint venture operating and project costs and amounts due from others, primarily related to derivatives, leases, buy/sell arrangements and product exchanges, which are accounted for outside the scope of ASC 606, Revenue from Contracts with Customers.
Contract assets and related costs are reflected in “Prepaid expenses and other current assets” and contract liabilities are reflected in “Accrued liabilities” and “Deferred credits and other noncurrent obligations” on the Consolidated Balance Sheet. Amounts for these items are not material to the company’s financial position.


25


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

First Quarter 2018 Compared with First Quarter 2017

Key Financial Results
Earnings by Business Segment
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Upstream
 
 
 
United States
$
648

 
$
80

International
2,704

 
1,437

Total Upstream
3,352

 
1,517

Downstream
 
 
 
United States
442

 
469

International
286

 
457

Total Downstream
728

 
926

Total Segment Earnings
4,080

 
2,443

All Other
(442
)
 
239

Net Income Attributable to Chevron Corporation (1) (2)
$
3,638

 
$
2,682

__________________________________________
 
 
 
(1) Includes foreign currency effects
$
129

 
$
(241
)
(2) Income net of tax; also referred to as “earnings” in the discussions that follow.
 
 
 
Net income attributable to Chevron Corporation for first quarter 2018 was $3.64 billion ($1.90 per share — diluted), compared with $2.68 billion ($1.41 per share — diluted) in the first three months of 2017.
Upstream earnings in first quarter 2018 were $3.35 billion compared to $1.52 billion in the corresponding 2017 period. The increase was mainly due to higher realizations and production.
Downstream earnings in first quarter 2018 were $728 million compared with $926 million in the corresponding 2017 period. The decrease was mainly due to lower margins on refined product sales, partially offset by lower tax expense, higher equity earnings from the 50 percent-owned Chevron Philips Chemical Company LLC and favorable foreign currency effects.
Refer to pages 30 through 31 for additional discussion of results by business segment and “All Other” activities for first quarter of 2018 versus the same period in 2017.
Business Environment and Outlook
Chevron Corporation* is a global energy company with substantial business activities in the following countries: Angola, Argentina, Australia, Azerbaijan, Bangladesh, Brazil, Canada, China, Colombia, Denmark, Indonesia, Kazakhstan, Myanmar, Nigeria, the Partitioned Zone between Saudi Arabia and Kuwait, Philippines, Republic of Congo, Singapore, South Africa, South Korea, Thailand, the United Kingdom, the United States, and Venezuela.
Earnings of the company depend mostly on the profitability of its upstream business segment. The biggest factor affecting the results of operations for the upstream segment is the price of crude oil. The price of crude oil has fallen significantly since mid-year 2014. The downturn in the price of crude oil has impacted the company's results of operations, cash flows, leverage, capital and exploratory investment program and production outlook. A sustained lower price environment could result in the impairment or write-off of specific assets in future periods. The company has responded with reductions in operating expenses, pacing and re-focusing of capital and exploratory expenditures, and increased asset sales. The company anticipates that crude oil prices will

_____________________
* Incorporated in Delaware in 1926 as Standard Oil Company of California, the company adopted the name Chevron Corporation in 1984 and ChevronTexaco Corporation in 2001. In 2005, ChevronTexaco Corporation changed its name to Chevron Corporation. As used in this report, the term “Chevron” and such terms as “the company,” “the corporation,” “our,” “we” , “us” and "its" may refer to Chevron Corporation, one or more of its consolidated subsidiaries, or all of them taken as a whole, but unless stated otherwise they do not include “affiliates” of Chevron — i.e., those companies accounted for by the equity method (generally owned 50 percent or less) or investments accounted for by the cost method. All of these terms are used for convenience only and are not intended as a precise description of any of the separate companies, each of which manages its own affairs.
26


increase in the future, as continued growth in demand and a slowing in supply growth should bring global markets into balance; however, the timing or sustainability of any such increase is unknown. In the company's downstream business, crude oil is the largest cost component of refined products. It is the company's objective to deliver competitive results and shareholder value in any business environment.
The effective tax rate for the company can change substantially during periods of significant earnings volatility. This is due to the mix effects that are impacted both by the absolute level of earnings or losses and whether they arise in higher or lower tax rate jurisdictions. As a result, a decline or increase in the effective tax rate in one period may not be indicative of expected results in future periods. Note 11 provides the company’s effective income tax rate for the first quarters of 2018 and 2017.
Refer to the "Cautionary Statement Relevant to Forward-Looking Information" on page 2 and to "Risk Factors" on pages 19 through 22 of the company’s 2017 Annual Report on Form 10-K for a discussion of some of the inherent risks that could materially impact the company's results of operations or financial condition.
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 value growth. The company's asset sale program for 2018 through 2020 is targeting before-tax proceeds of $5-10 billion. 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, technology advancements, production quotas or other actions imposed by the Organization of Petroleum Exporting Countries (OPEC) or other producers, actions of regulators, 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 including, among other things, the general level of inflation, 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. Cost pressures continue in the North America unconventional market, particularly the Permian Basin, with increases in commodity prices and higher levels of activity and investment.  International and offshore markets are beginning to see indications of increased cost pressure. Capital and exploratory expenditures and operating expenses could also be affected by damage to production facilities caused by severe weather or civil unrest, delays in construction, or other factors.


27


beochart1q18.jpg
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 $54 per barrel for the full-year 2017. During 2018, Brent averaged $67 per barrel in the first quarter and ended April at about $75. The majority of the company’s equity crude production is priced based on the Brent benchmark. Brent markets traded in a $60 to $70 per barrel range throughout most of the first quarter 2018 due to steady demand growth, lower inventory levels, and strong compliance with OPEC production cuts implemented in January 2017. Oil markets were also supported by heightened geopolitical uncertainty impacting key oil producing economies.
The WTI price averaged $51 per barrel for the full-year 2017. During 2018, WTI averaged $63 per barrel in the first quarter and ended April at about $69. WTI traded at a narrower discount to Brent in the 2018 first quarter relative to fourth quarter 2017 due to declining U.S. inventory levels, higher exports and reduced supply bottlenecks.
A differential in crude oil prices exists between high-gravity, low-sulfur crudes and low-gravity, high-sulfur crudes. The amount of the differential in any period is associated with the relative supply/demand balances for each crude type. In first quarter 2018, the differential widened in North America due primarily to stronger North America light-sweet crude demand.  Outside of North America, differentials narrowed as lower output from key producers continued to limit availability of heavier, more sour crudes.
Chevron has interests 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 sales prices.)
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. Fluctuations in the price of natural gas in the United States are closely associated with customer demand relative to the volumes produced and stored in North America. In the United States, prices at Henry Hub averaged $3.04 per thousand cubic feet (MCF) for the first three months of 2018, compared with $3.01 during the first three months of 2017. At the end of April 2018, the Henry Hub spot price was $2.68 per MCF.
Outside the United States, price changes for natural gas depend on a wide range of supply, demand and regulatory circumstances. Chevron sells natural gas into the domestic pipeline market in most locations. In some locations, Chevron has invested in long-term projects to produce and liquefy natural gas for transport by tanker to other markets. The company's long-term contract prices for liquefied natural gas (LNG) are typically linked to crude oil prices. Most of the equity LNG offtake from the operated Australian LNG projects is committed under binding long-term contracts, with the remainder to be sold in the Asian spot LNG market.  The Asian spot market reflects the supply and demand for LNG in the Pacific Basin and is not directly linked to crude oil prices. International natural gas sales prices averaged $5.85 per MCF during the first three months of 2018, compared with $4.36 per MCF in the same period last year. (See page 35 for the company’s average natural gas sales prices for the U.S. and international regions.)
The company’s worldwide net oil-equivalent production in the first three months of 2018 averaged 2.852 million barrels per day. About one-sixth of the company’s net oil-equivalent production in the first three months of 2018


28


occurred in the OPEC-member countries of Angola, Nigeria and Venezuela. OPEC quotas had no effect on the company’s net crude oil production for the first quarter of 2018 or 2017.
The company estimates that net oil-equivalent production for the full-year 2018 will grow 4 to 7 percent compared to 2017, assuming a Brent crude oil price of $60 per barrel and excluding the impact of anticipated 2018 asset sales. This estimate is subject to many factors and uncertainties, including quotas or other actions that may be imposed by OPEC; price effects on entitlement volumes; 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.
In the Partitioned Zone between Saudi Arabia and Kuwait, production was shut-in beginning in May 2015 as a result of difficulties in securing work and equipment permits. Net oil-equivalent production in the Partitioned Zone in 2014 was 81,000 barrels per day. During 2015, net oil-equivalent production averaged 28,000 barrels per day. As of early May 2018, production remained shut-in, and the exact timing of a production restart is uncertain and dependent on dispute resolution between Saudi Arabia and Kuwait. The financial effects from the loss of Partitioned Zone production have not been significant, and are not expected to be significant in 2018.
In April 2018, the company sold its interest in the Elk Hills Field in California, with proceeds to be reflected in second quarter results.
Refer to the “Results of Operations” section on page 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 and Gulf Coast of the United States, 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 page 31 for additional discussion of the company’s downstream operations.
All Other consists of worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities and technology companies.
Operating Developments
Noteworthy operating developments in recent months included the following:
United States — Chevron Phillips Chemical Company LLC, the company’s 50 percent-owned affiliate, commenced operations of a new ethane cracker at its Cedar Bayou facility in Baytown, Texas.


29


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 6, beginning on page 11, for a discussion of the company’s “reportable segments,” as defined under the accounting standards for segment reporting.)
Upstream
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
U.S. Upstream Earnings
$
648

 
$
80

U.S. upstream operations earned $648 million in first quarter 2018, compared to $80 million from the corresponding period in 2017. The improvement primarily reflected higher realizations and production of $430 and $180 million, respectively, partially offset by higher exploration expenses of $40 million.
The company’s average sales price per barrel of crude oil and natural gas liquids was $56 in first quarter 2018, up from $45 a year earlier. The average sales price of natural gas was $2.02 per thousand cubic feet in first quarter 2018, compared with $2.39 in first quarter 2017.
Net oil-equivalent production of 733,000 barrels per day in first quarter 2018 was up 61,000 barrels per day, or 9 percent, from a year earlier. Production increases from shale and tight properties in the Permian Basin in Texas and New Mexico, and base business in the Gulf of Mexico, were partially offset by the impact of asset sales of 39,000 barrels per day and normal field declines.
The net liquids component of oil-equivalent production in first quarter 2018 increased 13 percent to 567,000 barrels per day, while net natural gas production decreased 1 percent to 993 million cubic feet per day.
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
International Upstream Earnings*
$
2,704

 
$
1,437

___________________
 
 
 
*  Includes foreign currency effects
$
120

 
$
(274
)
International upstream operations earned $2.70 billion in first quarter 2018, compared with $1.44 billion from the corresponding period in 2017. The increase was primarily due to higher crude oil and natural gas realizations of $710 million and $210 million, respectively, higher natural gas sales volumes of $410 million and lower tax items of $190 million. Partially offsetting the increases were the absence of a gain of $600 million from the 2017 sale of the Indonesia geothermal business and higher depreciation expenses mostly associated with higher production of $130 million. Foreign currency effects had a favorable impact on earnings of $394 million between periods.
The average sales price per barrel of crude oil and natural gas liquids in first quarter 2018 was $61, compared with $49 a year earlier. The average sales price of natural gas in first quarter 2018 was $5.85 per thousand cubic feet, compared with $4.36 in first quarter 2017.
International net oil-equivalent production of 2.12 million barrels per day in first quarter 2018 increased 115,000 barrels per day, or 6 percent, from first quarter 2017. Production increases from major capital projects, primarily Gorgon and Wheatstone in Australia, were partially offset by production entitlement effects in several locations, normal field declines and the impact of asset sales of 22,000 barrels per day.
The net liquids component of oil-equivalent production of 1.19 million barrels per day in first quarter 2018 decreased 1 percent from first quarter 2017. Net natural gas production of 5.60 billion cubic feet per day in first quarter 2018 increased 17 percent from first quarter 2017.


30


Downstream
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
U.S. Downstream Earnings
$
442

 
$
469

U.S. downstream operations earned $442 million in first quarter 2018, compared with earnings of $469 million a year earlier. The decrease was primarily due to lower margins on refined product sales of $100 million and higher expenses from planned turnaround activity at the El Segundo, California refinery of $80 million. These were partially offset by lower tax expenses of $70 million, and higher equity earnings from the 50 percent-owned Chevron Phillips Chemical Company LLC of $60 million.
Refinery crude oil input in first quarter 2018 increased 2 percent to 930,000 barrels per day from the year-ago period. Refined product sales of 1.19 million barrels per day increased 3 percent from first quarter 2017 primarily due to increased jet fuel sales. Branded gasoline sales of 501,000 barrels per day decreased 2 percent from the 2017 period.
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
International Downstream Earnings*
$
286

 
$
457

___________________
 
 
 
*  Includes foreign currency effects
$
11

 
$
(46
)
International downstream operations earned $286 million in first quarter 2018, compared with $457 million a year earlier. The decrease in earnings was largely due to lower margins on refined product sales of $270 million, partially offset by lower operating expenses of $110 million. Foreign currency effects had a favorable impact on earnings of $57 million between periods.
Refinery crude oil input of 712,000 barrels per day in first quarter 2018 decreased 41,000 barrels per day from the year-ago period mainly due to the sale of the company’s Canadian refining asset in third quarter 2017.

Total refined product sales of 1.44 million barrels per day in first quarter 2018 were down 1 percent from the year-ago period, primarily due to lower diesel sales, partially offset by higher jet fuel sales.
All Other
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
(Charges)/Earnings*
$
(442
)
 
$
239

___________________
 
 
 
*  Includes foreign currency effects
$
(2
)
 
$
79

All Other consists of worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities and technology companies.
Net charges in first quarter 2018 were $442 million, compared with net earnings of $239 million a year earlier. The change between periods was mainly due to the absence of first quarter 2017 favorable corporate tax items and higher interest expense. Foreign currency effects increased net charges by $81 million between periods.


31


Consolidated Statement of Income
Explanations of variations between periods for selected income statement categories are provided below:
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Sales and other operating revenues
$
35,968

 
$
31,524

Sales and other operating revenues increased $4.44 billion in the first quarter, primarily due to higher refined product and crude oil prices, and higher natural gas prices and volumes. Beginning in 2018, excise, value-added and similar taxes collected on behalf of third parties were no longer included in "Sales and other operating revenues", but are netted in "Taxes other than on income" in accordance with ASU 2014-09. 2017 includes excise, value-added and similar taxes collected on behalf of third parties of $1.68 billion.
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Income from equity affiliates
$
1,637

 
$
1,150

Income from equity affiliates in the quarterly period increased mainly due to higher upstream-related earnings from Tengizchevroil in Kazakhstan, Petroboscan and Petropiar in Venezuela, and higher downstream-related earnings from CPChem.
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Other income
$
159

 
$
747

Other income for the three-month period decreased due to lower gains on asset sales, partially offset by a favorable swing in foreign currency effects.
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Purchased crude oil and products
$
21,233

 
$
17,506

Purchases increased $3.7 billion in the three-month period, primarily due to higher crude oil and refined product prices.
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Operating, selling, general and
administrative expenses
$
5,424

 
$
5,396

Operating, selling, general and administrative expenses were largely unchanged between quarterly periods.
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Exploration expenses
$
158

 
$
144

The increase in exploration expenses for the three-month period was mostly due to higher charges for well write-offs, partially offset by lower geological and geophysical expenses.


32


 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Depreciation, depletion and
amortization
$
4,289

 
$
4,194

Depreciation, depletion and amortization expenses for the first quarter increased mainly due to higher production levels for certain oil and gas producing fields partially offset by the impact of lower depreciation rates for certain oil and gas producing fields.
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Taxes other than on income
$
1,344

 
$
2,871

Beginning in 2018, excise, value-added and similar taxes collected on behalf of third parties were netted in "Taxes other than on income" and were no longer included in "Sales and other operating revenues," in accordance with ASU 2014-09. First quarter 2017 includes $1.68 billion in taxes collected on behalf of third parties. Partially offsetting the decrease were higher duties and higher other taxes reflecting increased refined product sales and production.
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Interest and debt expense
$
159

 
$
51

Interest and debt expenses for the first quarter increased mainly due to a decrease in the amount of interest capitalized.
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Other components of net periodic benefit costs
$
84

 
$
130

Other components of net periodic benefit costs for the first quarter decreased mainly due to an increase in plan asset values and decrease in amortization of actuarial and settlement losses. This line was added to the Consolidated Statement of Income in accordance with the adoption of ASU 2017-07.
 
Three Months Ended
March 31
 
2018
 
2017
 
(Millions of dollars)
Income tax expense
$
1,414

 
$
430

The increase in income tax expense in 2018 of $984 million is consistent with the increase in total income before tax for the company of $1.94 billion.
U.S. income before tax increased from $237 million in 2017 to $862 million in 2018. This increase in income was primarily driven by the effect of higher crude oil prices and production. The increase in income had a direct impact on the company’s U.S. income tax cost which was partially offset by the lower U.S. statutory tax rate. This resulted in an increase in tax expense of $609 million between year-over-year periods, from a tax benefit of $388 million in 2017 to a tax charge of $221 million in 2018. Contributing to the first quarter 2017 results were U.S. tax adjustments.


33


International income before tax increased from $2.89 billion in 2017 to $4.21 billion in 2018. This $1.32 billion increase was primarily driven by the effect of higher prices and production, offset by the absence of the gain on the 2017 sale of the company’s geothermal assets in Indonesia. The higher prices and production primarily drove the $375 million increase in international income tax expense between year-over-year periods, from $818 million in 2017 to $1.19 billion in 2018.
Refer also to the discussion of the effective income tax rate in Note 11 on page 16.


34


Selected Operating Data
The following table presents a comparison of selected operating data:

Selected Operating Data (1)(2) 

Three Months Ended
March 31

2018
 
2017
U.S. Upstream



Net crude oil and natural gas liquids production (MBPD)
567

 
504

Net natural gas production (MMCFPD)(3)
993

 
1,006

Net oil-equivalent production (MBOEPD)
733

 
672

Sales of natural gas (MMCFPD)
3,408

 
3,142

Sales of natural gas liquids (MBPD)
100

 
29

Revenue from net production
 
 
 
Liquids ($/Bbl)
$
56.12

 
$
44.83

Natural gas ($/MCF)
$
2.02

 
$
2.39

International Upstream
 
 
 
Net crude oil and natural gas liquids production (MBPD)(4)
1,186

 
1,204

Net natural gas production (MMCFPD)(3)
5,600

 
4,801

Net oil-equivalent production (MBOEPD)(4)
2,119

 
2,004

Sales of natural gas (MMCFPD)
5,475

 
4,933

Sales of natural gas liquids (MBPD)
35

 
23

Revenue from liftings
 
 
 
Liquids ($/Bbl)
$
61.13

 
$
48.56

Natural gas ($/MCF)
$
5.85

 
$
4.36

U.S. and International Upstream
 
 
 
Total net oil-equivalent production (MBOEPD)(4)
2,852

 
2,676

U.S. Downstream
 
 
 
Gasoline sales (MBPD)(5)
601

 
584

Other refined product sales (MBPD)
584

 
569