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,~~September 30, 2017

o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

Commission file number 001-00368

Chevron Corporation

(Exact name of registrant as specified in its charter)



Delaware		94-0890210
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)
6001 Bollinger Canyon Road, San Ramon, California		94583-2324 (Zip Code)
(Address of principal executive offices)

Registrant’s telephone number, including area code: (925) 842-1000

NONE

(Former name, former address and former fiscal year, if changed since last report.)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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,~~September 30, 2017
Common stock, $.75 par value		~~1,894,556,806~~1,899,373,928

Table of Contents

~~INDEX~~TABLE OF CONTENTS



		Page No.
	Cautionary Statements Relevant to Forward-Looking Information for the Purpose of “Safe Harbor” Provisions of the Private Securities Litigation Reform Act of 1995	2
PART I FINANCIAL INFORMATION
Item 1.	Consolidated Financial Statements —
	Consolidated Statement of Income for the Three and Nine Months Ended ~~March 31,~~September 30, 2017, and 2016	3
	Consolidated Statement of Comprehensive Income for the Three and Nine Months Ended ~~March 31,~~September 30, 2017, and 2016	4
	Consolidated Balance Sheet at ~~March 31,~~September 30, 2017, and December 31, 2016	5
	Consolidated Statement of Cash Flows for the ~~Three~~Nine Months Ended ~~March 31,~~September 30, 2017, and 2016	6
	Notes to Consolidated Financial Statements	7-23
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	~~24-34~~24-36
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	3536
Item 4.	Controls and Procedures	3536
PART II OTHER INFORMATION
Item 1.	Legal Proceedings	36
Item 1A.	Risk Factors	3637
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	3637
Item 5.	Other Information	37
Item 6.	Exhibits	3738
Signature		3839
~~Exhibits:~~	~~Computation of Ratio of Earnings to Fixed Charges~~	40
~~Rule 13a-14(a)/15d-14(a) Certifications~~		~~41-42~~
~~Rule 13a-14(b)/15d-14(b) Certifications~~		~~43-44~~

Table of Contents

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,” “goals,” “objectives,” ~~“strategies”~~“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 its 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 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 20 through 22 of the company’s 2016 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.

Table of Contents

PART I.

FINANCIAL INFORMATION


Item 1.	Consolidated Financial Statements

CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF INCOME

(Unaudited)


	Three Months Ended March 31					Three Months Ended September 30					Nine Months Ended September 30
	2017		2016			2017		2016			2017		2016
	(Millions of dollars, except per-share amounts)					(Millions of dollars, except per-share amounts)
Revenues and Other Income
Sales and other operating revenues*	$	31,524	$	23,070		$	33,892	$	29,159		$	98,293	$	80,073
Income from equity affiliates	1,150		576			1,036		555			3,502		1,883
Other income (loss)	747		(93		)
Other income						1,277		426			2,311		1,019
Total Revenues and Other Income	33,421		23,553			36,205		30,140			104,106		82,975
Costs and Other Deductions
Purchased crude oil and products	17,506		11,225			18,776		15,842			54,607		42,345
Operating expenses	4,656		5,404			4,937		4,666			14,255		15,124
Selling, general and administrative expenses	870		998			1,238		1,109			3,099		3,140
Exploration expenses	144		370			239		258			508		842
Depreciation, depletion and amortization	4,194		4,403			5,109		4,130			14,614		15,254
Taxes other than on income*	2,871		2,864			3,213		2,962			9,149		8,799
Interest and debt expense	51		—			35		64			134		143
Total Costs and Other Deductions	30,292		25,264			33,547		29,031			96,366		85,647
Income (Loss) Before Income Tax Expense	3,129		(1,711		)	2,658		1,109			7,740		(2,672		)
Income Tax Expense (Benefit)	430		(1,004		)	672		(192		)	1,589		(1,803		)
Net Income (Loss)	2,699		(707		)	1,986		1,301			6,151		(869		)
Less: Net income attributable to noncontrolling interests	17		18			34		18			67		43
Net Income (Loss) Attributable to Chevron Corporation	$	2,682	$	(725	)	$	1,952	$	1,283		$	6,084	$	(912	)
Per Share of Common Stock:
Net Income (Loss) Attributable to Chevron Corporation
— Basic	$	1.43	$	(0.39	)	$	1.03	$	0.68		$	3.23	$	(0.49	)
— Diluted	$	1.41	$	(0.39	)	$	1.03	$	0.68		$	3.21	$	(0.49	)
Dividends	$	1.08	$	1.07		$	1.08	$	1.07		$	3.24	$	3.21
Weighted Average Number of Shares Outstanding (000s)
— Basic	1,879,372		1,869,775			1,882,650		1,873,649			1,881,026		1,871,813
— Diluted	1,895,393		1,869,775			1,895,879		1,883,342			1,894,764		1,871,813
____________________
* Includes excise, value-added and similar taxes:	$	1,677	$	1,652		$	1,867	$	1,772		$	5,315	$	5,208

See accompanying notes to consolidated financial statements.

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CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended March 31						Three Months Ended September 30						Nine Months Ended September 30
	2017			2016			2017			2016			2017			2016
	(Millions of dollars)						(Millions of dollars)
Net Income (Loss)	$	2,699		$	(707	)	$	1,986		$	1,301		$	6,151		$	(869	)
Currency translation adjustment	14			9			13			7			37			9
Unrealized holding gain on securities:
Net gain (loss) arising during period	(5		)	9
Unrealized holding (loss) gain on securities:
Net (loss) gain arising during period							(2		)	21			(7		)	31
Defined benefit plans:
Actuarial gain (loss):
Amortization to net income of net actuarial and settlement losses	171			181			264			265			609			644
Actuarial loss arising during period	(14		)	—
Actuarial gain (loss) arising during period							3			(9		)	(11		)	(23		)
Prior service cost:
Amortization to net income of net prior service costs	(5		)	5			(5		)	2			(15		)	15
Defined benefit plans sponsored by equity affiliates	6			9			5			5			15			19
Income tax expense on defined benefit plans	(50		)	(72		)	(96		)	(102		)	(207		)	(247		)
Total	108			123			171			161			391			408
Other Comprehensive Gain, Net of Tax	117			141			182			189			421			448
Comprehensive Income (Loss)	2,816			(566		)	2,168			1,490			6,572			(421		)
Comprehensive income attributable to noncontrolling interests	(17		)	(18		)	(34		)	(18		)	(67		)	(43		)
Comprehensive Income (Loss) Attributable to Chevron Corporation	$	2,799		$	(584	)	$	2,134		$	1,472		$	6,505		$	(464	)

See accompanying notes to consolidated financial statements.

Table of Contents

CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEET

(Unaudited)


		At March 31 2017			At December 31 2016				At September 30 2017			At December 31 2016
		(Millions of dollars, except per-share amounts)							(Millions of dollars, except per-share amounts)
ASSETS	ASSETS							ASSETS
Cash and cash equivalents		$	6,983		$	6,988			$	6,641		$	6,988
Marketable securities		11			13				13			13
Accounts and notes receivable, net		13,754			14,092				14,124			14,092
Inventories
Crude oil and petroleum products		3,315			2,720				3,156			2,720
Chemicals		437			455				516			455
Materials, supplies and other		2,169			2,244				2,089			2,244
Total inventories		5,921			5,419				5,761			5,419
Prepaid expenses and other current assets		2,899			3,107				2,859			3,107
Total Current Assets		29,568			29,619				29,398			29,619
Long-term receivables, net		2,457			2,485				3,016			2,485
Investments and advances		30,915			30,250				32,402			30,250
Properties, plant and equipment, at cost		336,150			336,077				343,066			336,077
Less: Accumulated depreciation, depletion and amortization		155,854			153,891				164,630			153,891
Properties, plant and equipment, net		180,296			182,186				178,436			182,186
Deferred charges and other assets		6,980			6,838				6,793			6,838
Goodwill		4,543			4,581				4,531			4,581
Assets held for sale		4,352			4,119				584			4,119
Total Assets		$	259,111		$	260,078			$	255,160		$	260,078
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY							LIABILITIES AND EQUITY
Short-term debt		$	8,297		$	10,840			$	7,897		$	10,840
Accounts payable		13,078			13,986				13,084			13,986
Accrued liabilities		4,657			4,882				5,085			4,882
Federal and other taxes on income		1,414			1,050				1,123			1,050
Other taxes payable		980			1,027				1,034			1,027
Total Current Liabilities		28,426			31,785				28,223			31,785
Long-term debt		36,864			35,193				33,983			35,193
Capital lease obligations		95			93				92			93
Deferred credits and other noncurrent obligations		21,515			21,553				20,830			21,553
Noncurrent deferred income taxes		17,276			17,516				17,438			17,516
Noncurrent employee benefit plans		7,145			7,216				6,683			7,216
Total Liabilities*		111,321			113,356				107,249			113,356
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, 2017, and December 31, 2016)		1,832			1,832
Common stock (authorized 6,000,000,000 shares; $0.75 par value; 2,442,676,580 shares issued at September 30, 2017, and December 31, 2016)									1,832			1,832
Capital in excess of par value		16,631			16,595				16,745			16,595
Retained earnings		173,698			173,046				173,035			173,046
Accumulated other comprehensive loss		(3,726		)	(3,843		)		(3,422		)	(3,843		)
Deferred compensation and benefit plan trust		(240		)	(240		)		(240		)	(240		)
Treasury stock, at cost (548,119,774 and 551,170,158 shares at March 31, 2017, and December 31, 2016, respectively)		(41,603		)	(41,834		)
Treasury stock, at cost (543,302,652 and 551,170,158 shares at September 30, 2017, and December 31, 2016, respectively)									(41,237		)	(41,834		)
Total Chevron Corporation Stockholders’ Equity		146,592			145,556				146,713			145,556
Noncontrolling interests		1,198			1,166				1,198			1,166
Total Equity		147,790			146,722				147,911			146,722
Total Liabilities and Equity		$	259,111		$	260,078			$	255,160		$	260,078
____________________
* Refer to Note 14, "Other Contingencies and Commitments" beginning on page 19.
* Refer to Note 14, "Other Contingencies and Commitments" beginning on page 20.								* Refer to Note 14, "Other Contingencies and Commitments" beginning on page 20.

See accompanying notes to consolidated financial statements.

Table of Contents

CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF CASH FLOWS

(Unaudited)


	Three Months Ended March 31						Nine Months Ended September 30
	2017			2016			2017			2016
	(Millions of dollars)						(Millions of dollars)
Operating Activities
Net Income (Loss)	$	2,699		$	(707	)	$	6,151		$	(869	)
Adjustments
Depreciation, depletion and amortization	4,194			4,403			14,614			15,254
Dry hole expense	7			262			140			472
Distributions less than income from equity affiliates	(652		)	(219		)	(2,122		)	(708		)
Net before-tax gains on asset retirements and sales	(764		)	(27		)	(2,139		)	(872		)
Net foreign currency effects	131			212			145			321
Deferred income tax provision	(563		)	(1,089		)	(464		)	(3,139		)
Net increase in operating working capital	(957		)	(993		)	(695		)	(1,266		)
Decrease (increase) in long-term receivables	20			(68		)
Increase in long-term receivables							(537		)	(81		)
Net (increase) decrease in other deferred charges	(32		)	3			(57		)	30
Cash contributions to employee pension plans	(170		)	(461		)	(825		)	(697		)
Other	(34		)	(175		)	74			538
Net Cash Provided by Operating Activities	3,879			1,141			14,285			8,983
Investing Activities
Capital expenditures	(3,315		)	(5,566		)	(9,763		)	(14,100		)
Proceeds and deposits related to asset sales	2,087			82			4,856			2,209
Net maturities of time deposits	—			—
Net sales (purchases) of marketable securities	2			—
Net (borrowing) repayment of loans by equity affiliates	(6		)	(92		)
Net sales (purchases) of other short-term investments	(7		)	67
Net sales of marketable securities							—			2
Net borrowing of loans by equity affiliates							(36		)	(2,195		)
Net (purchases) sales of other short-term investments							(19		)	155
Net Cash Used for Investing Activities	(1,239		)	(5,509		)	(4,962		)	(13,929		)
Financing Activities
Net borrowings (repayments) of short-term obligations	(3,928		)	3,802
Net (repayments) borrowings of short-term obligations							(7,185		)	869
Proceeds from issuance of long-term debt	3,994			—			3,991			6,924
Repayments of long-term debt and other financing obligations	(966		)	(14		)	(1,028		)	(812		)
Cash dividends — common stock	(2,029		)	(2,000		)	(6,093		)	(6,007		)
Distributions to noncontrolling interests	—			—			(66		)	(57		)
Net sales of treasury shares	245			123			649			359
Net Cash Provided by Financing Activities	(2,684		)	1,911
Net Cash (Used for) Provided by Financing Activities							(9,732		)	1,276
Effect of Exchange Rate Changes on Cash and Cash Equivalents	39			(3		)	62			(1		)
Net Change in Cash and Cash Equivalents	(5		)	(2,460		)	(347		)	(3,671		)
Cash and Cash Equivalents at January 1	6,988			11,022			6,988			11,022
Cash and Cash Equivalents at March 31	$	6,983		$	8,562
Cash and Cash Equivalents at September 30							$	6,641		$	7,351

See accompanying notes to consolidated financial statements.

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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~~three- and nine-month periods ended ~~March 31,~~September 30, 2017, are not necessarily indicative of future financial results. The term “earnings” is defined as net income (loss) 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 2016 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~~nine months ending ~~March 31,~~September 30, 2017, are reflected in the table below.

Changes in Accumulated Other Comprehensive Income (Loss) by Component ⁽¹⁾

~~(Millions of Dollars)~~


		Three Months Ended March, 31, 2017																Nine Months Ended September 30, 2017
		Currency Translation Adjustment			Unrealized Holding Gains (Losses) on Securities			Derivatives			Defined Benefit Plans			Total				Currency Translation Adjustment			Unrealized Holding Gains (Losses) on Securities			Derivatives			Defined Benefit Plans			Total
																		(Millions of dollars)
Balance at January 1		$	(162	)	$	(2	)	$	(2	)	$	(3,677	)	$	(3,843	)		$	(162	)	$	(2	)	$	(2	)	$	(3,677	)	$	(3,843	)
Components of Other Comprehensive Income (Loss):	Components of Other Comprehensive Income (Loss):																Components of Other Comprehensive Income (Loss):
Before Reclassifications		14			(5		)	—			2			11				37			(7		)	—			10			40
Reclassifications⁽²⁾		—			—			—			106			106				—			—			—			381			381
Net Other Comprehensive Income (Loss)		14			(5		)	—			108			117				37			(7		)	—			391			421
Balance at March 31		$	(148	)	$	(7	)	$	(2	)	$	(3,569	)	$	(3,726	)
Balance at September 30																		$	(125	)	$	(9	)	$	(2	)	$	(3,286	)	$	(3,422	)

⁽¹⁾ All amounts are net of tax.

⁽²⁾ Refer to Note 10, Employee Benefits for reclassified components totaling ~~$166~~$594 million that are included in employee benefit costs for the ~~three~~nine months ending ~~March 31, 2017~~.September 30, 2017. Related income taxes for the same period, totaling ~~$60~~$213 million, are reflected in ~~Income~~"Income Tax ~~Expense~~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~~nine months of 2017 and 2016 is as follows:


	2017								2016									2017									2016
	Chevron Corporation Stockholders’ Equity			Non-controlling Interest		Total Equity			Chevron Corporation Stockholders’ Equity			Non-controlling Interest			Total Equity			Chevron Corporation Stockholders’ Equity			Non-controlling Interest			Total Equity			Chevron Corporation Stockholders’ Equity			Non-controlling Interest			Total Equity
	(Millions of dollars)																	(Millions of dollars)
Balance at January 1	$	145,556		$	1,166	$	146,722		$	152,716		$	1,170		$	153,886		$	145,556		$	1,166		$	146,722		$	152,716		$	1,170		$	153,886
Net income (loss)	2,682			17		2,699			(725		)	18			(707		)	6,084			67			6,151			(912		)	43			(869		)
Dividends	(2,030		)	—		(2,030		)	(2,001		)	—			(2,001		)	(6,095		)	—			(6,095		)	(6,009		)	—			(6,009		)
Distributions to noncontrolling interests	—			—		—			—			—			—			—			(66		)	(66		)	—			(57		)	(57		)
Treasury shares, net	231			—		231			143			—			143			597			—			597			375			—			375
Other changes, net*	153			15		168			174			(19		)	155			571			31			602			630			(4		)	626
Balance at March 31	$	146,592		$	1,198	$	147,790		$	150,307		$	1,169		$	151,476
Balance at September 30																		$	146,713		$	1,198		$	147,911		$	146,800		$	1,152		$	147,952

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

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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						Nine Months Ended September 30
	2017			2016			2017			2016
	(Millions of dollars)						(Millions of dollars)
Decrease in accounts and notes receivable	$	317		$	468
Increase in inventories	(550		)	(176		)
Decrease (increase) in prepaid expenses and other current assets	209			(241		)
Decrease (increase) in accounts and notes receivable							$	265		$	(455	)
(Increase) decrease in inventories							(436		)	232
Decrease in prepaid expenses and other current assets							196			844
Decrease in accounts payable and accrued liabilities	(1,178		)	(1,039		)	(729		)	(1,783		)
Increase (decrease) in income and other taxes payable	245			(5		)	9			(104		)
Net increase in operating working capital	$	(957	)	$	(993	)	$	(695	)	$	(1,266	)

“Net Cash Provided by Operating Activities” included the following cash payments for interest on debt and for income taxes:


	Three Months Ended March 31				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)				(Millions of dollars)
Interest on debt (net of capitalized interest)	$	—	$	—	$	30	$	28
Income taxes	494		453		2,203		1,492

"Other" includes changes in postretirement benefits obligations and other long-term liabilities.

Information related to "Restricted Cash" is included on page 2122 in Note 15 under the heading "Restricted Cash."

The “Net sales ~~(purchases)~~ of marketable securities” consisted of the following gross amounts:


	Three Months Ended March 31					Nine Months Ended September 30
	2017		2016			2017			2016
	(Millions of dollars)					(Millions of dollars)
Marketable securities purchased	$	—	$	(6	)	$	(3	)	$	(9	)
Marketable securities sold	2		6			3			11
Net sales of marketable securities	$	2	$	—		$	—		$	2

The “Net ~~(borrowing) repayment~~borrowing of loans by equity affiliates” consisted of the following gross amounts:


	Three Months Ended March 31						Nine Months Ended September 30
	2017			2016			2017			2016
	(Millions of dollars)						(Millions of dollars)
Borrowing of loans by equity affiliates	$	(70	)	$	(96	)	$	(142	)	$	(2,271	)
Repayment of loans by equity affiliates	64			4			106			76
Net borrowing of loans by equity affiliates	$	(6	)	$	(92	)	$	(36	)	$	(2,195	)

The “Net (purchases) sales ~~(purchases)~~ of other short-term investments” consisted of the following gross amounts:


	Three Months Ended March 31						Nine Months Ended September 30
	2017			2016			2017			2016
	(Millions of dollars)						(Millions of dollars)
Purchases of other short-term investments	$	(9	)	$	(13	)	$	(26	)	$	—
Sales of other short-term investments	2			80			7			155
Net sales of other short-term investments	$	(7	)	$	67
Net (purchases) sales of other short-term investments							$	(19	)	$	155

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

The “Net (repayments) borrowings ~~(repayments)~~ of short-term obligations" consisted of the following gross and net amounts:


	Three Months Ended March 31						Nine Months Ended September 30
	2017			2016			2017			2016
	(Millions of dollars)						(Millions of dollars)
Repayments of short-term obligations	$	(2,952	)	$	(3,152	)	$	(8,403	)	$	(8,415	)
Proceeds from issuances of short-term obligations	3,415			2,831			3,415			11,695
Net borrowings of short-term obligations with three months or less maturity	(4,391		)	4,123			(2,197		)	(2,411		)
Net borrowings of short-term obligations	$	(3,928	)	$	3,802
Net (repayments) borrowings of short-term obligations							$	(7,185	)	$	869

The “Net sales of treasury shares” represents the cost of common shares acquired less the cost of shares issued for share-based compensation plans. Purchases totaled $1 million for the first ~~three~~nine months in 2017 and $2 million for the first nine months in 2016. No purchases were made under the company's share repurchase program in the first ~~three~~nine months of 2017 or 2016.

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				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)				(Millions of dollars)
Additions to properties, plant and equipment	$	3,305	$	5,285	$	9,615	$	13,757
Additions to investments	3		115		16		38
Current year dry hole expenditures	7		166		131		305
Payments for other liabilities and assets, net					1		—
Capital expenditures	3,315		5,566		9,763		14,100
Expensed exploration expenditures	137		108		368		370
Assets acquired through capital lease obligations	1		4		3		4
Capital and exploratory expenditures, excluding equity affiliates	3,453		5,678		10,134		14,474
Company’s share of expenditures by equity affiliates	939		791		3,252		2,693
Capital and exploratory expenditures, including equity affiliates	$	4,392	$	6,469	$	13,386	$	17,167

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Note 5. New Accounting Standards

Revenue Recognition (Topic 606): Revenue from Contracts with Customers. In July 2015, the FASB approved a one-year deferral of the effective date of ASU 2014-09, which becomes effective for the company January 1, 2018. The standard provides a single comprehensive revenue recognition model for contracts with customers, eliminates most industry-specific revenue recognition guidance, and expands disclosure requirements. The company has elected to adopt the standard using the modified retrospective transition method. "Sales and Other Operating Revenues” on the Consolidated Statement of Income includes excise, value-added and similar taxes on sales transactions. Upon adoption of the standard, revenue will exclude sales-based taxes collected on behalf of third parties, which will have no impact to earnings. The company's implementation efforts are focused on accounting policy and disclosure updates and system enhancements necessary to meet the standard's requirements. The company ~~continues to evaluate~~does not expect the ~~effect~~implementation of the standard to have a material effect on its consolidated financial statements.

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.

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.

Intangibles - Goodwill and Other (Topic 350) In January 2017, the FASB issued ASU 2017-04. The standard simplifies the accounting for goodwill impairment, and the company has chosen to early adopt beginning January 1, 2017. Early adoption has no effect on the company's consolidated financial statements.

Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20) In March 2017, the FASB issued ASU 2017-05 which becomes effective for the company January 1, 2018. The standard provides clarification regarding the guidance on accounting for the derecognition of nonfinancial assets. The company is evaluating the effect of the standard on its consolidated financial statements.

Compensation - Retirement Benefits (Topic 715) In March 2017, the FASB issued ASU 2017-07 which becomes effective for the company January 1, 2018. 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 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).

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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~~three- and nine-month periods ended ~~March 31,~~September 30, 2017 and 2016, are presented in the following table:


	Three Months Ended March 31						Three Months Ended September 30						Nine Months Ended September 30
Segment Earnings	2017			2016			2017			2016			2017			2016
	(Millions of dollars)						(Millions of dollars)
Upstream
United States	$	80		$	(850	)	$	(26	)	$	(212	)	$	(48	)	$	(2,175	)
International	1,437			(609		)	515			666			2,907			(1,292		)
Total Upstream	1,517			(1,459		)	489			454			2,859			(3,467		)
Downstream
United States	469			247			640			523			1,743			1,307
International	457			488			1,174			542			2,192			1,771
Total Downstream	926			735			1,814			1,065			3,935			3,078
Total Segment Earnings	2,443			(724		)	2,303			1,519			6,794			(389		)
All Other
Interest expense	(43		)	—			(30		)	(53		)	(115		)	(120		)
Interest income	15			15			13			15			42			47
Other	267			(16		)	(334		)	(198		)	(637		)	(450		)
Net Income (Loss) Attributable to Chevron Corporation	$	2,682		$	(725	)	$	1,952		$	1,283		$	6,084		$	(912	)

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,~~September 30, 2017, and December 31, 2016, are as follows:


Segment Assets	At March 31 2017		At December 31 2016		At September 30 2017		At December 31 2016
	(Millions of dollars)				(Millions of dollars)
Upstream
United States	$	42,096	$	42,596	$	40,318	$	42,596
International	163,151		164,068		161,058		164,068
Goodwill	4,543		4,581		4,531		4,581
Total Upstream	209,790		211,245		205,907		211,245
Downstream
United States	22,590		22,264		22,635		22,264
International	16,123		15,816		16,619		15,816
Total Downstream	38,713		38,080		39,254		38,080
Total Segment Assets	248,503		249,325		245,161		249,325
All Other
United States	4,974		4,852		4,169		4,852
International	5,634		5,901		5,830		5,901
Total All Other	10,608		10,753		9,999		10,753
Total Assets — United States	69,660		69,712		67,122		69,712
Total Assets — International	184,908		185,785		183,507		185,785
Goodwill	4,543		4,581		4,531		4,581
Total Assets	$	259,111	$	260,078	$	255,160	$	260,078

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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~~three- and nine-month periods ended ~~March 31,~~September 30, 2017 and 2016, 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						Three Months Ended September 30						Nine Months Ended September 30
Sales and Other Operating Revenues	2017			2016			2017			2016			2017			2016
	(Millions of dollars)						(Millions of dollars)
Upstream
United States	$	3,240		$	2,072		$	3,245		$	2,847		$	9,620		$	7,386
International	6,581			5,021			7,191			5,927			20,624			16,325
Subtotal	9,821			7,093			10,436			8,774			30,244			23,711
Intersegment Elimination — United States	(2,241		)	(1,331		)	(2,298		)	(1,979		)	(6,737		)	(5,120		)
Intersegment Elimination — International	(2,720		)	(1,929		)	(2,828		)	(2,742		)	(8,256		)	(6,949		)
Total Upstream	4,860			3,833			5,310			4,053			15,251			11,642
Downstream
United States	12,432			9,167			13,452			11,958			39,206			32,841
International	14,513			10,308			15,298			13,415			44,512			36,262
Subtotal	26,945			19,475			28,750			25,373			83,718			69,103
Intersegment Elimination — United States	(3		)	(4		)	(5		)	(4		)	(11		)	(12		)
Intersegment Elimination — International	(330		)	(263		)	(216		)	(303		)	(818		)	(762		)
Total Downstream	26,612			19,208			28,529			25,066			82,889			68,329
All Other
United States	235			249			260			280			773			825
International	5			8			6			10			19			29
Subtotal	240			257			266			290			792			854
Intersegment Elimination — United States	(183		)	(220		)	(207		)	(240		)	(621		)	(724		)
Intersegment Elimination — International	(5		)	(8		)	(6		)	(10		)	(18		)	(28		)
Total All Other	52			29			53			40			153			102
Sales and Other Operating Revenues
United States	15,907			11,488			16,957			15,085			49,599			41,052
International	21,099			15,337			22,495			19,352			65,155			52,616
Subtotal	37,006			26,825			39,452			34,437			114,754			93,668
Intersegment Elimination — United States	(2,427		)	(1,555		)	(2,510		)	(2,223		)	(7,369		)	(5,856		)
Intersegment Elimination — International	(3,055		)	(2,200		)	(3,050		)	(3,055		)	(9,092		)	(7,739		)
Total Sales and Other Operating Revenues	$	31,524		$	23,070		$	33,892		$	29,159		$	98,293		$	80,073

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.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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


	Three Months Ended March 31					Nine Months Ended September 30
	2017		2016			2017		2016
	(Millions of dollars)					(Millions of dollars)
Sales and other operating revenues	$	24,408	$	16,864		$	75,759	$	60,882
Costs and other deductions	24,099		17,996			75,403		63,596
Net income (loss) attributable to CUSA	421		(444		)	1,315		(917		)


	At March 31 2017		At December 31 2016		At September 30 2017		At December 31 2016
	(Millions of dollars)				(Millions of dollars)
Current assets	$	10,936	$	11,266	$	11,566	$	11,266
Other assets	55,452		55,722		53,826		55,722
Current liabilities	16,284		16,660		15,777		16,660
Other liabilities	15,497		21,701		15,337		21,701
Total CUSA net equity	$	34,607	$	28,627	$	34,278	$	28,627
Memo: Total debt	$	3,054	$	9,418	$	3,057	$	9,418

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				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)				(Millions of dollars)
Sales and other operating revenues	$	3,395	$	2,260	$	9,619	$	7,355
Costs and other deductions	1,754		1,393		4,806		5,172
Net income attributable to TCO	1,158		604		3,402		1,534

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				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)				(Millions of dollars)
Sales and other operating revenues	$	2,445	$	1,923	$	6,816	$	6,302
Costs and other deductions	2,019		1,555		5,732		5,127
Net income attributable to CPChem	503		459		1,424		1,343

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. Beginning in 2017, medical coverage for Medicare-eligible retirees in the company's main U.S. medical plan is provided through a third-party private exchange. 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.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

The components of net periodic benefit costs for 2017 and 2016 are as follows:


	Three Months Ended March 31						Three Months Ended September 30						Nine Months Ended September 30
	2017			2016			2017			2016			2017			2016
	(Millions of dollars)						(Millions of dollars)
Pension Benefits
United States
Service cost	$	122		$	123		$	122		$	123		$	366		$	370
Interest cost	91			94			91			95			274			283
Expected return on plan assets	(149		)	(181		)	(149		)	(181		)	(447		)	(542		)
Amortization of prior service credits	(1		)	(2		)	(1		)	(2		)	(3		)	(6		)
Amortization of actuarial losses	85			84			85			84			255			251
Settlement losses	78			81			169			162			325			324
Total United States	226			199			317			281			770			680
International
Service cost	37			40			38			37			114			120
Interest cost	53			67			54			68			164			198
Expected return on plan assets	(58		)	(62		)	(61		)	(61		)	(178		)	(184		)
Amortization of prior service costs	3			4			3			1			9			11
Amortization of actuarial losses	9			11			11			14			33			37
Settlement losses	—			—			—			1			—			18
Total International	44			60			45			60			142			200
Net Periodic Pension Benefit Costs	$	270		$	259		$	362		$	341		$	912		$	880
Other Benefits*
Service cost	$	8		$	15		$	8		$	15		$	24		$	45
Interest cost	23			32			23			32			71			96
Amortization of prior service costs	(7		)	3			(7		)	3			(21		)	10
Amortization of actuarial losses	(1		)	5			(1		)	5			(4		)	15
Net Periodic Other Benefit Costs	$	23		$	55		$	23		$	55		$	70		$	166

* 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,~~September 30, 2017, a total of ~~$170~~$825 million was contributed to employee pension plans (including ~~$95~~$681 million to the U.S. ~~plans.)~~plans). Total contributions for the full year are currently estimated to be ~~$450~~$950 million ($~~200~~700 million for the U.S. plans and $250 million for the international ~~plans.) The company anticipates it will not make contributions to the primary U.S. pension plan for the remainder of 2017.~~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~~nine months of 2017, the company contributed ~~$35~~$115 million to its OPEB plans. The company anticipates contributing approximately ~~$128~~$48 million during the remainder of ~~2017~~.2017.

Note 11. Income Taxes

The 2017 increase in income tax expense between quarterly periods of ~~$1.43 billion between periods,~~$864 million, from a benefit of ~~$1.0~~$192 million in 2016 to a charge of $672 million in 2017, 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. The company’s effective tax rate changed between periods from (17) percent in 2016 to 25 percent in 2017. 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. The reduction in statutory tax rates in the United Kingdom in the 2016 quarter also impacted the 2016 effective tax rate.

The 2017 increase in income tax expense for the nine months of $3.4 billion, from a benefit of $1.8 billion in 2016 to a charge of ~~$430 million~~$1.6 billion in 2017, 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 ~~the sale of the company’s geothermal assets~~gains on asset sales primarily in ~~Indonesia.~~Indonesia and Canada. The company’s effective tax rate changed between periods from 5967 percent in 2016 to

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

21 percent in 2017. The change in effective tax rate is primarily a consequence of ~~higher crude oil prices as well as~~ the mix effect resulting from the absolute level of earnings or losses and whether they arose in higher or lower tax rate jurisdictions.

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,~~September 30, 2017. For these jurisdictions, the latest years for which income tax examinations had been finalized were as follows: United States — 2011, Nigeria — 2000, Angola — ~~2009~~2015, Australia — 2006 and Kazakhstan — 2007.

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~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)~~

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.

~~The company is currently assessing the impact of an~~On April 21, 2017, an adverse decision was issued by the full Federal Court of Australia regarding the interest rate to be applied on certain Chevron intercompany loans. AtOn August 14, 2017, an agreement was reached with the Australian Taxation Office to settle this ~~time, it is~~dispute. Management believes the agreed terms to be a reasonable resolution of the dispute, which did not ~~possible to determine whether~~have a material impact on the ~~decision will result in a significant change in~~year-to-date results of the ~~company’s unrecognized tax benefit within the next 12 months. Any such change would impact the company’s effective tax rate.~~company.

Note 12. Assets Held For Sale

At ~~March 31,~~September 30, 2017, the company classified ~~$4.35 billion~~$584 million 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 2016 and the first ~~three~~nine months of 2017 were not material.

The company's Bangladesh operations previously classified as "held for sale" were deemed to be "held and used" in the third quarter 2017 and reclassified to "Properties, plant and equipment" on the Consolidated Balance Sheet.

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 seven 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 government granted Texpet and all related corporate entities a full release from any and all environmental liability arising from the consortium operations.

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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

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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 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

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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.

On July 2, 2013, the provincial court in Lago Agrio issued an embargo order in Ecuador ordering that any funds to be paid by the Government of Ecuador to Chevron to satisfy a $96 million award issued in an unrelated action by an arbitral tribunal presiding in the Permanent Court of Arbitration in The Hague under the Rules of the United Nations Commission on International Trade Law must be paid to the Lago Agrio plaintiffs. The award was issued by the tribunal under the United States-Ecuador Bilateral Investment Treaty in an action filed in 2006 in

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connection with seven breach of contract cases that Texpet filed against the Government of Ecuador between 1991 and 1993. The Government of Ecuador has moved to set aside the tribunal's award. On September 26, 2014, the Supreme Court of the Netherlands issued an opinion denying Ecuador’s set aside request. A Federal District Court for the District of Columbia confirmed the tribunal's award, and, on August 4, 2015, a panel of the U.S. Court of Appeals for the District of Columbia Circuit affirmed the District Court's decision. On September 28, 2015, the Court of Appeals denied the Government of Ecuador’s request for full appellate court review of the Federal District Court’s decision. On June 6, 2016, the United States Supreme Court denied the Government of Ecuador's petition for Writ of Certiorari. On July 22, 2016, the Government of Ecuador paid the $96 million award, plus interest, resulting in a payment to Chevron of approximately $113 million.

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

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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 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 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.

~~Table~~ On November 1, 2017, the National Court, First Instance, of ~~Contents~~

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Argentina issued a decision dismissing the Lago Agrio plaintiffs' enforcement proceeding based on jurisdictional grounds.

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 February 9, 2011, the Tribunal issued an Order for Interim Measures requiring the Republic of Ecuador to take all measures at its disposal to suspend or cause to be suspended the enforcement or recognition within and without Ecuador of any judgment against Chevron in the Lago Agrio case pending further order of the Tribunal. On January 25, 2012, the Tribunal converted the Order for Interim Measures into an Interim Award. Chevron filed a renewed application for further interim measures on January 4, 2012, and the Republic of Ecuador opposed Chevron’s application and requested that the existing Order for Interim Measures be vacated on January 9, 2012. On February 16, 2012, the Tribunal issued a Second Interim Award mandating that the Republic of Ecuador take all measures necessary (whether by its judicial, legislative or executive branches) to suspend or cause to be suspended the enforcement and recognition within and without Ecuador of the judgment against Chevron and, in particular, to preclude any certification by the Republic of Ecuador that would cause the judgment to be enforceable against Chevron. On February 27, 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.”

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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.

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 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 is seeking relief that includes a declaration that any judgment against Chevron in the Lago Agrio litigation is the result of fraud and other unlawful conduct and is therefore unenforceable. On March 7, 2011, the Federal District Court issued a preliminary injunction prohibiting the Lago

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Agrio plaintiffs and persons acting in concert with them from taking any action in furtherance of recognition or enforcement of any judgment against Chevron in the Lago Agrio case pending resolution of Chevron’s civil lawsuit by the Federal District Court. On May 31, 2011, the Federal District Court severed claims one through eight of Chevron’s complaint from the ninth claim for declaratory relief and imposed a discovery stay on claims one through eight pending a trial on the ninth claim for declaratory relief. On September 19, 2011, the U.S. Court of Appeals for the Second Circuit vacated the preliminary injunction, stayed the trial on Chevron’s ninth claim, a claim for declaratory relief, that had been set for November 14, 2011, and denied the defendants’ mandamus petition to recuse the judge hearing the lawsuit. The Second Circuit issued its opinion on January 26, 2012 ordering the dismissal of Chevron’s ninth claim for declaratory relief. On February 16, 2012, the Federal District Court lifted the stay on claims one through eight, and on October 18, 2012, the Federal District Court set a trial date of October 15, 2013. On March 22, 2013, Chevron settled its claims against Stratus Consulting, and on April 12, 2013 sworn declarations by representatives of Stratus Consulting were filed with the Court admitting their role and that of the plaintiffs' attorneys in drafting the environmental report of the mining engineer appointed by the provincial court in Lago Agrio. On September 26, 2013, the Second Circuit denied the defendants' Petition for Writ of Mandamus to recuse the judge hearing the case and to collaterally estop Chevron from seeking a declaration that the Lago Agrio judgment was obtained through fraud and other unlawful conduct.

The trial commenced on October 15, 2013 and concluded on November 22, 2013. On March 4, 2014, the Federal District Court entered a judgment in favor of Chevron, prohibiting the defendants from seeking to enforce the Lago Agrio judgment in the United States and further prohibiting them from profiting from their illegal acts. The defendants 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.

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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 14 and 15 for a discussion of the periods for which tax returns have been audited for the company’s major tax jurisdictions.

As discussed in Note 11, on page 15, the company ~~is currently assessing the impact of~~received an adverse decision on April 21, 2017, ~~adverse decision issued by the Federal Court of Australia~~ regarding the interest rate to be applied on certain Chevron intercompany loans. AtOn August 14, 2017, an agreement was reached with the Australian Taxation Office to settle this ~~time, it is~~dispute. Management believes the agreed terms to be a reasonable resolution of the dispute, which did not ~~possible to determine whether the decision will result in a significant change in the company’s unrecognized tax benefit, which may~~ have a material ~~effect~~impact on the ~~company’s~~year-to-date results of ~~operations in any one reporting period.~~the company. The company does not expect settlement of income tax liabilities associated with ~~other~~ uncertain tax positions to have a material effect on ~~the~~its consolidated financial position or ~~equity.~~liquidity.

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

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is solely responsible until April 2022, when the indemnification expires. The environmental conditions or events that are subject to these indemnities must have arisen prior to the sale of the assets in 1997.

Although the company has provided for known obligations under this indemnity that are probable and reasonably estimable, the amount of additional future costs may be material to results of operations in the period in which they are recognized. The company does not expect these costs will have a material effect on its consolidated financial position or liquidity.

Off-Balance-Sheet Obligations The company and its subsidiaries have certain contingent liabilities with respect to long-term unconditional purchase obligations and commitments, including throughput and take-or-pay agreements, some of which relate to suppliers’ financing arrangements. The agreements typically provide goods and services, such as pipeline and storage capacity, drilling rigs, utilities, and petroleum products, to be used or sold in the ordinary course of the company’s business.

Environmental The company is subject to loss contingencies pursuant to laws, regulations, private claims and legal proceedings related to environmental matters that are subject to legal settlements or that in the future may require the company to take action to correct or ameliorate the effects on the environment of prior release of chemicals or petroleum substances, including MTBE, by the company or other parties. Such contingencies may exist for various sites, including, but not limited to, federal Superfund sites and analogous sites under state laws, refineries, crude oil fields, service stations, terminals, land development areas, and mining activities, whether operating, closed or divested. These future costs are not fully determinable due to such factors as the unknown magnitude of possible contamination, the unknown timing and extent of the corrective actions that may be required, the determination of the company’s liability in proportion to other responsible parties, and the extent to which such costs are recoverable from third parties.

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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 On November 7, 2011, while drilling a development well in the deepwater Frade Field about 75 miles offshore Brazil, an unanticipated pressure spike caused oil to migrate from the well bore through a series of fissures to the sea floor, emitting approximately 2,400 barrels of oil. The source of the seep was substantially contained within four days and the well was plugged and abandoned. On March 14, 2012, the company identified a small, second seep in a different part of the field. No evidence of any coastal or wildlife impacts related to either of these seeps has emerged. As reported in the company’s previously filed periodic reports, it has resolved civil claims relating to these incidents brought by a Brazilian federal district prosecutor. As also reported previously, the federal district prosecutor also filed criminal charges against Chevron and 11 Chevron employees. These charges were dismissed by the trial court on February 19, 2013, reinstated by an appellate court on October 9, 2013, and then, upon Chevron's motion for reconsideration, dismissed by the appellate court on August 27, 2015. The federal district prosecutor has appealed the appellate court’s decision.

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.

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Level 2: Inputs other than Level 1 that are observable, either directly or indirectly. For the company, Level 2 inputs include quoted prices for similar assets or liabilities, prices obtained through third-party broker quotes and prices that can be corroborated with other observable inputs for substantially the complete term of a contract.

Level 3: Unobservable inputs. The company does not use Level 3 inputs for any of its recurring fair value measurements. Level 3 inputs may be required for the determination of fair value associated with certain nonrecurring measurements of nonfinancial assets and liabilities.

The fair value hierarchy for assets and liabilities measured at fair value on a recurring basis at ~~March 31,~~September 30, 2017, and December 31, 2016, is as follows:

Assets and Liabilities Measured at Fair Value on a Recurring Basis

(Millions of dollars)


	At March 31, 2017								At December 31, 2016								At September 30, 2017								At December 31, 2016
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
Marketable Securities	$	11	$	11	$	—	$	—	$	13	$	13	$	—	$	—	$	13	$	13	$	—	$	—	$	13	$	13	$	—	$	—
Derivatives	73		51		22		—		32		15		17		—		10		1		9		—		32		15		17		—
Total Assets at Fair Value	$	84	$	62	$	22	$	—	$	45	$	28	$	17	$	—	$	23	$	14	$	9	$	—	$	45	$	28	$	17	$	—
Derivatives	8		1		7		—		109		78		31		—		147		130		17		—		109		78		31		—
Total Liabilities at Fair Value	$	8	$	1	$	7	$	—	$	109	$	78	$	31	$	—	$	147	$	130	$	17	$	—	$	109	$	78	$	31	$	—

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,~~September 30, 2017.

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

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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,~~September 30, 2017, and December 31, 2016, 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 ~~$7.0~~$6.6 billion and $7.0 billion at ~~March 31,~~September 30, 2017, and December 31, 2016, 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,~~September 30, 2017.

Restricted Cash had a carrying/fair value of ~~$1.1~~$1.3 billion and $1.4 billion at ~~March 31,~~September 30, 2017, and December 31, 2016, respectively. At ~~March 31,~~September 30, 2017, 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 and funds held in escrow pending tax deferred exchanges, 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 ~~$27.9~~$25.0 billion and $26.2 billion at ~~March 31,~~September 30, 2017, and December 31, 2016, respectively. The fair value of long-term debt at ~~March 31,~~September 30, 2017, and December 31, 2016 was ~~$28.4~~$25.7 billion and $26.6 billion, respectively. Long-term debt primarily includes corporate issued bonds. The fair value of corporate bonds classified as Level 1 is ~~$27.7~~$25.0 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,~~September 30, 2017, and December 31, 2016, were not material.

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~~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,~~September 30, 2017, is as follows:

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

(Millions of dollars)


	At March 31, 2017										At September 30, 2017
																						Before-Tax Loss
	Total		Level 1		Level 2		Level 3		Before-Tax Loss		Total		Level 1			Level 2			Level 3			Three Months Ended			Nine Months Ended
											Total					Level 2			Level 3			Three Months Ended			Nine Months Ended
Properties, plant and equipment, net (held and used)	$	—	$	—	$	—	$	—	$	81	$	106	Level 1		$	—		$	—		$	106		$	36		$	654
Properties, plant and equipment, net (held for sale)	502		—		502		—		76		115		—			115			—			11			290
Investments and advances	10		—		—		10		3		12		—			—			12			8			14
Total Assets at Fair Value	$	512	$	—	$	502	$	10	$	160	$	233	$	—		$	115		$	118		$	55		$	958

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~~third quarter 2017.

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~~third quarter 2017.

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.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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,~~September 30, 2017, and December 31, 2016, 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
2017 At December 31
2016
Commodity Accounts and notes receivable, net $ 70
$ 30
Commodity Long-term receivables, net 3
2
Total Assets at Fair Value $ 73
$ 32
Commodity Accounts payable $ 6
$ 99
Commodity Deferred credits and other noncurrent obligations 2
10
Total Liabilities at Fair Value $ 8
$ 109

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~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)~~



Type of Contract	Balance Sheet Classification	At September 30 2017		At December 31 2016
Commodity	Accounts and notes receivable, net	$	10	$	30
Commodity	Long-term receivables, net	—		2
Total Assets at Fair Value		$	10	$	32
Commodity	Accounts payable	$	145	$	99
Commodity	Deferred credits and other noncurrent obligations	2		10
Total Liabilities at Fair Value		$	147	$	109

Consolidated Statement of Income: The Effect of Derivatives Not Designated as Hedging Instruments

(Millions of dollars)


		Gain / (Loss) Three Months Ended March 31							Gain / (Loss) Three Months Ended September 30						Gain / (Loss) Nine Months Ended September 30
Type of Contract	Statement of Income Classification	2017			2016			Statement of Income Classification	2017			2016			2017			2016
Commodity	Sales and other operating revenues	$	162		$	(26	)	Sales and other operating revenues	$	(196	)	$	(23	)	$	82		$	(194	)
Commodity	Purchased crude oil and products	4			(4		)	Purchased crude oil and products	(7		)	4			3			(17		)
Commodity	Other income	(2		)	(1		)	Other income	1			(3		)	(2		)	(1		)
		$	164		$	(31	)		$	(202	)	$	(22	)	$	83		$	(212	)

The table below represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at ~~March 31,~~September 30, 2017, and December 31, 2016.

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				Gross Amount Recognized		Gross Amounts Offset		Net Amounts Presented			Gross Amounts Not Offset			Net Amount
At March 31, 2017				Gross Amounts Offset						Gross Amounts Not Offset				Net Amount				Gross Amount Recognized		Gross Amounts Offset		Net Amounts Presented			Gross Amounts Not Offset			Net Amount
At September 30, 2017																		Gross Amount Recognized		Gross Amounts Offset		Net Amounts Presented			Gross Amounts Not Offset			Net Amount
Derivative Assets	Gross Amount Recognized		$	999		$	Net Amounts Presented		926			$	73			$	—	Gross Amount Recognized		Gross Amounts Offset		Net Amounts Presented		$	Gross Amounts Not Offset		73	Net Amount
Derivative Liabilities	$	934		$	926		$	8		$	—			$	8			$	1,869	$	1,722	$	147		$	—		$	147

At December 31, 2016
Derivative Assets	$	1,052		$	1,020		$	32		$	—			$	32			$	1,052	$	1,020	$	32		$	—		$	32
Derivative Liabilities	$	1,129		$	1,020		$	109		$	—			$	109			$	1,129	$	1,020	$	109		$	—		$	109

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. Long-Term Debt~~

In February 2017, the company issued $450 million in aggregate principal amount of floating rate notes due 2019, $550 million in aggregate principal amount of 1.686 percent notes due 2019, $400 million in aggregate principal amount of floating rate notes due 2020, $600 million in aggregate principal amount of 1.991 percent notes due 2020, $300 million in aggregate principal amount of floating rate notes due 2022, $700 million in aggregate principal amount of 2.498 percent notes due 2022, and $1.0 billion in aggregate principal amount of 2.895 percent notes due 2024. In February 2017, $900 million of Chevron Corporation floating rate notes were repaid at maturity.

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

~~First~~Third Quarter 2017 Compared with ~~First~~Third Quarter 2016

And Nine Months 2017 Compared with Nine Months 2016

Key Financial Results

Earnings by Business Segment


	Three Months Ended March 31						Three Months Ended September 30						Nine Months Ended September 30
	2017			2016			2017			2016			2017			2016
	(Millions of dollars)						(Millions of dollars)
Upstream
United States	$	80		$	(850	)	$	(26	)	$	(212	)	$	(48	)	$	(2,175	)
International	1,437			(609		)	515			666			2,907			(1,292		)
Total Upstream	1,517			(1,459		)	489			454			2,859			(3,467		)
Downstream
United States	469			247			640			523			1,743			1,307
International	457			488			1,174			542			2,192			1,771
Total Downstream	926			735			1,814			1,065			3,935			3,078
Total Segment Earnings	2,443			(724		)	2,303			1,519			6,794			(389		)
All Other	239			(1		)	(351		)	(236		)	(710		)	(523		)
Net Income (Loss) Attributable to Chevron Corporation ^{(1) (2)}	$	2,682		$	(725	)	$	1,952		$	1,283		$	6,084		$	(912	)
_____________________
__________________________________________
⁽¹⁾ Includes foreign currency effects	$	(241	)	$	(319	)	$	(112	)	$	72		$	(351	)	$	32
⁽²⁾ Income net of tax; also referred to as “earnings” in the discussions that follow.							⁽²⁾ Income net of tax; also referred to as “earnings” in the discussions that follow.

Net income attributable to Chevron Corporation for third quarter 2017 was $1.95 billion ($1.03 per share — diluted), compared with earnings of $1.28 billion ($0.68 per share — diluted) in the corresponding 2016 period. Net income attributable to Chevron Corporation for the first ~~three~~nine months of 2017 was ~~$2,682 million~~$6.08 billion ($~~1.41~~3.21 per share — diluted), compared with a loss of ~~$725~~$912 million ~~($0.39~~($0.49 per share — diluted) in the first ~~three~~nine months of 2016.

Upstream earnings in third quarter 2017 were $489 million compared with $454 million a year earlier. The increase was mainly due to higher crude oil realizations, and higher natural gas and crude production, partially offset by higher depreciation expenses and higher tax items. Earnings for the first nine months of ~~2016.~~2017 were $2.86 billion compared with a loss of $3.47 billion a year earlier. The increase was due to higher crude oil realizations, increased natural gas sales volumes, higher gains on asset sales, lower depreciation expense primarily due to lower impairments, and lower operating expenses.

~~Upstream~~Downstream earnings in ~~first~~third quarter 2017 were ~~$1.52~~$1.81 billion compared ~~to a loss of $1.46~~with $1.07 billion in the corresponding 2016 period. The increase was ~~mainly~~ due to ~~higher crude oil sales prices, higher~~ gains on asset sales ~~lower operating expenses~~ and higher ~~natural gas sale volumes.~~

~~Downstream~~ ~~earnings in~~margins on refined product sales, partially offset by higher operating expenses. Earnings for the first ~~quarter~~nine months of 2017 were ~~$926 million~~$3.94 billion compared with ~~$735 million~~$3.08 billion in the corresponding 2016 period. The increase was ~~mainly~~ due to higher margins on refined product sales, gains on asset sales, and the absence of a ~~first quarter~~ 2016 asset ~~impairment and~~impairment. Partially offsetting the increase was lower ~~operating expenses.~~shipping results.

Refer to pages 28 through 2931 for additional discussion of results by business segment and “All Other” activities for third quarter and first ~~quarter~~nine months of 2017 versus the same ~~period~~periods in 2016.

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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, Democratic Republic of the Congo, Denmark, Indonesia, Kazakhstan, Myanmar, Nigeria, the Partitioned Zone between Saudi Arabia and Kuwait, Philippines, Republic of Congo, Singapore, South Africa, South Korea, Thailand, ~~Trinidad and Tobago,~~ 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 is responding 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 increase in the future, as continued growth in demand and a slowing in supply growth should bring global markets into

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balance; however, the timing 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~~third quarters of 2017 and 2016.

Refer to the "Cautionary Statement Relevant to Forward-Looking Information" on page 2 and to "Risk Factors" on pages 20 through 22 of the company’s 2016 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 2016 and 2017 is targeting before-tax proceeds of $5-10 billion. Proceeds and deposits related to asset sales were $2.8 billion in 2016 and ~~$2.1~~$4.9 billion in the first ~~three~~nine months of 2017. Refer to the "Results of Operations" section beginning on page 28 for discussions of net gains on asset sales during 2017. ~~Refer to "Operating Developments" on page 27 and 28 for further information regarding the company's asset dispositions.~~ 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 inventory levels, technology advancements, production quotas or other actions imposed by the Organization of Petroleum Exporting Countries (OPEC), 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.

_____________________

^* 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” and “us” 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.

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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. ~~As a result~~Costs in some North American unconventional plays are starting to rise with higher levels of activity and investment. Costs outside of the North American unconventional space continue to decline ~~in prices of crude~~driven by reduced investment and the lower oil ~~and other commodities since mid-2014, these costs have declined.~~price environment. Capital and exploratory expenditures and operating expenses ~~can~~could also be affected by damage to production facilities caused by severe weather or civil unrest, delays in construction, or other factors.

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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 $44 per barrel for the full-year 2016. During 2017, Brent averaged ~~$54~~$52 per barrel in the ~~first~~third quarter, and ended ~~April~~October at about ~~$50.~~$61. The majority of the company’s equity crude production is priced based on the Brent benchmark. Brent markets ~~traded~~trended higher in a ~~$50-~~$47-$5557 per barrel range throughout ~~most~~the third quarter of ~~the~~ 2017, ~~first quarter driven by steady~~as strong seasonal demand ~~growth~~ and hurricane-related disruptions tightened global markets, while rising geopolitical tensions created additional uncertainty. Ongoing strong compliance among OPEC producers on production cuts implemented beginning in ~~January. Oil markets were also supported by heightened geopolitical uncertainty~~January 2017, and ~~renewed supply disruptions~~discussions about potentially extending the agreement beyond its currently-planned expiration in ~~Libya. However, price recovery was limited by persistently high global inventory levels and the return of U.S. production growth stemming from a recovery in activity.~~first quarter 2018, further reinforced market confidence.

The WTI price averaged $43 per barrel for the full-year 2016. During 2017, WTI averaged ~~$52~~$48 per barrel in the ~~first~~third quarter, and ended ~~April~~October at about ~~$49.~~$54. The WTI ~~traded at a wider~~ discount to Brent inwidened significantly over the third quarter of 2017 ~~first quarter~~ relative to ~~fourth quarter 2016 due~~first-half 2017 as persistently rising inventories at Cushing led to ~~persistently high~~concerns of renewed infrastructure constraints, and hurricane activity interrupted exports that caused total U.S. crude oil inventory levels ~~growing U.S. production, and the seasonal reduction in U.S. refinery runs.~~to briefly rise.

A differential in crude oil prices exists between high quality (high-gravity, low-sulfur) crudes and those of lower quality (low-gravity, high-sulfur). The amount of the differential in any period is associated with the relative supply/demand balances for each crude ~~type, which are functions of the capacity of refineries that are able to process each as feedstock into high-value light products (motor gasoline, jet fuel, aviation gasoline and diesel fuel).~~type. In ~~first~~third quarter 2017, the differential ~~narrowed~~remained relatively stable in North ~~America due to reduced global availability of heavier, more sour, crudes and reduced support for U.S. light sweet crude prices as a result of U.S. production growth.~~America. Outside of North America, differentials ~~narrowed~~widened as ~~lower output from key Middle East producers increased values of heavier, more sour crudes.~~strong refinery demand combined with maintenance in the North Sea and unplanned outages in Libya tightened light sweet crude markets.

Chevron produces or shares in the production of heavy crude oil in California, Indonesia, the Partitioned Zone between Saudi Arabia and Kuwait, Venezuela and in certain fields in Angola, China and the United Kingdom sector of the North Sea. (See page 3233 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 for natural gas in the United States are closely associated with customer demand relative to the volumes produced in North America. In the United States, prices at Henry Hub averaged ~~$3.01~~$3.00 per thousand cubic feet (MCF) for the first ~~three~~nine months of 2017, compared with ~~$1.99~~$2.29 during the first ~~three~~nine months of 2016. At the end of ~~April~~October 2017, the Henry Hub spot price was ~~$3.17~~$2.77 per MCF.

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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 continues to invest in long-term projects to install infrastructure 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 ~~$4.36~~$4.50 per MCF during the first ~~three~~nine months of 2017, compared with ~~$3.91~~$4.01 per MCF in the same period last year. (See page 3233 for the company’s average natural gas sales prices for the U.S. and international regions.)

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The company’s worldwide net oil-equivalent production in the first ~~three~~nine months of 2017 averaged ~~2.676~~2.724 million barrels per day. About one-sixth of the company’s net oil-equivalent production in the first ~~three~~nine months of 2017 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~~third quarter of 2017 or 2016.

The company estimates that net oil-equivalent production for the full-year 2017 will grow 46 to 98 percent compared to 2016, assuming a Brent crude oil price of $50 per barrel and before the effect of anticipated asset sales. The impact of 2017 asset sales on full-year production is expected to be ~~in the range of 50,000 to 100,000~~approximately 30,000 barrels of oil-equivalent per ~~day, depending on the timing of the close of individual transactions~~day.. The estimate of full-year production 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 certain upstream projects can begin well in advance of the start of the associated crude oil and natural gas production. A significant majority of Chevron’s upstream investment is made outside the United States.

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~~November 2017, 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 production in 2015 and 2016 were not significant and are not expected to be significant in 2017.

Refer to the “Results of Operations” section on pages 28 and 29 for additional discussion of the company’s upstream business.

Downstream Earnings for the downstream segment are closely tied to margins on the refining, manufacturing and marketing of products that include gasoline, diesel, jet fuel, lubricants, fuel oil, fuel and lubricant additives, and petrochemicals. Industry margins are sometimes volatile and can be affected by the global and regional supply-and-demand balance for refined products and petrochemicals, and by changes in the price of crude oil, other refinery and petrochemical feedstocks, and natural gas. Industry margins can also be influenced by inventory levels, geopolitical events, costs of materials and services, refinery or chemical plant capacity utilization, maintenance programs, and disruptions at refineries or chemical plants resulting from unplanned outages due to severe weather, fires or other operational events.

Other factors affecting profitability for downstream operations include the reliability and efficiency of the company’s refining, marketing and petrochemical assets, the effectiveness of its crude oil and product supply functions, and the volatility of tanker-charter rates for the company’s shipping operations, which are driven by the industry’s demand for crude oil and product tankers. Other factors beyond the company’s control include the general level of inflation and energy costs to operate the company’s refining, marketing and petrochemical assets.

The company’s most significant marketing areas are the West Coast ~~of North America, the U.S.~~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.

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Refer to the “Results of Operations” section on pages 29 and 30 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:

~~Angola~~ ~~— Commenced production from the main production facility of the Mafumeira Sul Project.~~

Australia ~~— Achieved first LNG from Train 3 at the Gorgon Project.~~

~~Bangladesh~~ — Announced ~~agreement to sell upstream operations.~~

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~~Canada~~ ~~— Signed agreement to sell refining~~first LNG production and ~~marketing assets in British Columbia and Alberta.~~

~~Indonesia~~ ~~— Completed~~first cargo shipment from Train 1 at the ~~sale of the geothermal business.~~

~~South Africa and Botswana~~ ~~— Signed agreement to sell refining, fuels and lubricants assets.~~ Wheatstone LNG Project.

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 10, for a discussion of the company’s “reportable segments,” as defined under the accounting standards for segment reporting.)

Upstream

Three Months Ended
March 31
2017 2016
(Millions of dollars)
U.S. Upstream Earnings $ 80
$ (850 )



	Three Months Ended September 30						Nine Months Ended September 30
	2017			2016			2017			2016
	(Millions of dollars)
U.S. Upstream Earnings	$	(26	)	$	(212	)	$	(48	)	$	(2,175	)

U.S. upstream operations ~~earned $80 million in~~ ~~first quarter2017, compared to~~incurred a loss of ~~$850~~$26 million in third quarter 2017, compared with a loss of $212 million from a year ago. The improvement reflected higher crude oil and natural gas realizations of $160 million.

U.S. upstream incurred a loss of $48 million for the ~~corresponding period~~first nine months of 2017, compared with a loss of $2.18 billion from a year earlier. The improvement in ~~2016. The increase~~earnings was primarily due to higher crude oil and natural gas realizations of ~~$540 million~~$1.0 billion and lower depreciation ~~and~~expenses of $580 million, primarily from lower impairment charges of $360 million. Lower operating expenses of ~~$150~~$190 million and ~~$90~~higher gains on asset sales of $180 million ~~respectively.~~also contributed to the improvement.

The ~~company’s~~ average ~~sales price~~realization per barrel for U.S. crude oil and natural gas liquids in ~~first~~third quarter2017 was ~~$45~~,$42, up from $37 a year ago. The average nine-month realization per barrel for U.S. crude oil and natural gas liquids was $43 in 2017, compared ~~with~~ ~~$26~~to $33 a year earlier. The average ~~sales price of~~ natural gas realization in ~~first~~third quarter2017 was ~~$2.39~~$1.80 per thousand cubic feet, compared with ~~$1.32~~$1.89 in ~~first quarter~~ ~~2016~~.2016. The average nine-month natural gas realization was $2.17 per thousand cubic feet in 2017 and $1.47 in 2016.

Net oil-equivalent production of ~~672,000~~681,000 barrels per day in ~~first~~third quarter2017 was down ~~29,000~~17,000 barrels per day, or 42 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 more than offset by the impact of asset sales of 67,000 barrels per day, and normal field declines. Net oil-equivalent production of 684,000 barrels per day in the first nine months of 2017 was down 10,000 barrels per day, or 1 percent, from a year earlier. Production increases from base business in the Gulf of Mexico and shale and tight properties in the Permian Basin in Texas and New Mexico, ~~and the Jack/St. Malo major capital project~~ were more than offset by the ~~impact~~effect of asset sales of ~~68,000~~62,000 barrels per day and normal field declines.

The net liquids component of oil-equivalent production of ~~504,000~~525,000 barrels per day in third quarter 2017 was up 1 percent from the corresponding 2016 period. The net liquids component of oil-equivalent production of 520,000 barrels per day in the ~~first quarter~~2017 nine-month period was up 3 percent from the ~~corresponding~~ 2016 period. Net natural gas production was ~~1.01 billion~~932 million cubic feet per day in ~~first~~third quarter2017,, a decrease of 2113 percent from the ~~corresponding~~ 2016 ~~period.~~ comparative period, primarily as a result of asset sales. Net natural gas production was 988 million cubic feet per day in the nine-month period, a decrease of 14 percent from the 2016 period, primarily as a result of asset sales.

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	Three Months Ended March 31						Three Months Ended September 30					Nine Months Ended September 30
	2017			2016			2017			2016		2017			2016
	(Millions of dollars)						(Millions of dollars)
International Upstream Earnings*	$	1,437		$	(609	)	$	515		$	666	$	2,907		$	(1,292	)
___________________
* Includes foreign currency effects	$	(274	)	$	(298	)	$	(164	)	$	85	$	(441	)	$	116

International upstream operations earned ~~$1.44~~$515 million in third quarter 2017, compared with $666 million a year ago. The decrease in earnings was mainly due to higher depreciation expense of $790 million including the effect of catch-up depreciation of $220 million for the Bangladesh operations that the company no longer intends to sell and an asset write-off of $220 million. Also contributing to the decrease were higher tax expenses of $250 million and the absence of an Ecuador arbitration award of $70 million. More than offsetting these items were higher crude oil and natural gas realizations of $380 million and $100 million, respectively, higher natural gas and crude oil sales volumes of $310 million and $170 million, respectively, and higher equity income from the absence of a TCO royalty expense of $320 million. Foreign currency effects had an unfavorable impact on earnings of $249 million between periods.

Earnings for the first nine months of 2017 were $2.91 billion in ~~first quarter2017~~, compared with a loss of ~~$609 million~~$1.29 billion from ~~the corresponding period in 2016.~~a year earlier. The increase in earnings was primarily due to higher crude oil realizations of ~~$1.14~~$1.88 billion, ~~a gain of approximately $600 million from the sale of the Indonesia geothermal business,~~ higher natural gas sales volumes of ~~$310~~$950 million, ~~and~~higher gains on asset sales of $690 million, higher equity income from the absence of a TCO royalty expense of $320 million, lower operating expenses of ~~$220 million. Partially offsetting these effects were higher depreciation~~$320 million, lower tax expenses of ~~$130~~$210 million, and ~~higher tax items~~lower exploration expenses of ~~$120~~$160 million. Foreign currency effects ~~decreased~~had an unfavorable impact on earnings ~~by $274~~of $557 million ~~in the~~ ~~2017~~ ~~quarter, compared with a decrease of $298 million a year earlier.~~between periods.

The average ~~sales price~~realization per barrel of crude oil and natural gas liquids in ~~first~~third quarter2017 was ~~$49,~~$48, compared with ~~$29~~$41 a year earlier. The average ~~sales price~~realization per barrel of crude oil and natural gas liquids in the first ~~quarter~~nine months of 2017 was ~~$4.36~~$47, compared with $37 a year earlier. The average natural gas realization in third quarter 2017 was $4.76 per thousand cubic feet, compared with ~~$3.91~~$4.18 in the 2016 period. The average natural gas realization in the first ~~quarter~~nine months of 2017 was $4.50 per thousand cubic feet, compared with $4.01 in the 2016. period.

International net oil-equivalent production of ~~2.00~~2.04 million barrels per day in ~~first~~third quarter2017 ~~increased 39,000~~ was up 221,000 barrels per day, or 212 percent, from ~~first quarter 2016.~~the corresponding 2016 period. Production increases from major capital projects, primarily Gorgon and ~~base business~~Angola LNG, and lower planned turnaround effects at Tengizchevroil, were partially offset by production entitlement effects in several locations and normal field ~~declines~~declines.

International net oil-equivalent production of 2.04 million barrels per day in the first nine months of 2017 was up 165,000 barrels per day, or 9 percent, from the corresponding 2016 period. Production increases from major capital projects and ~~the~~lower planned maintenance-related downtime were partially offset by production entitlement effects ~~of civil unrest~~ in ~~Nigeria.~~several locations and normal field declines.

The net liquids component of oil-equivalent production of ~~1.20~~1.19 million barrels per day in ~~first~~third quarter2017 ~~decreased 7~~ increased 5 percent from the 2016 period. The net liquids component of oil-equivalent production of 1.21 million barrels per day in the first ~~quarter~~nine months of 2017 was essentially unchanged from the corresponding 2016. period. Net natural gas production of ~~4.80~~5.05 billion cubic feet per day in ~~first~~third quarter2017 increased 1925 percent from the 2016 period. Net natural gas production of 5.00 billion cubic feet per day in the first nine months of 2017 increased 25 percent from the 2016 period.

Downstream



	Three Months Ended September 30				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)
U.S. Downstream Earnings	$	640	$	523	$	1,743	$	1,307

U.S. downstream operations earned $640 million in third quarter~~2016~~. 2017, compared with earnings of $523 million a year earlier. The increase in earnings was primarily due to higher margins on refined product sales of $120 million.

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~~Downstream~~Earnings for the first nine months of 2017 were $1.74 billion, compared to $1.31 billion a year earlier. The increase was due to higher margins on refined product sales of $280 million, the absence of an asset impairment of $110 million, and lower operating expenses of $90 million. Partially offsetting this increase were the absence of 2016 asset sale gains of $60 million.

Refinery crude oil input in third quarter 2017 decreased 4 percent from the year-ago period to 931,000 barrels per day. For the first nine months of 2017, crude oil input was 924,000 barrels per day, down 4 percent from the corresponding 2016 period. Refined product sales of 1.23 million barrels per day decreased 2 percent from third quarter 2016. Branded gasoline sales of 540,000 barrels per day decreased 2 percent from third quarter 2016. Refined product sales of 1.21 million barrels per day in the nine-month period were down 3 percent from the first nine months of 2016. Branded gasoline sales of 531,000 barrels per day for the first nine months decreased 1 percent from the corresponding 2016 period. Refinery crude oil input and refined product sales were lower in both comparative periods due to divestment of the Hawaii refining and marketing assets in fourth quarter 2016.

Three Months Ended
March 31
2017 2016
(Millions of dollars)
U.S. Downstream Earnings $ 469
$ 247



	Three Months Ended September 30					Nine Months Ended September 30
	2017		2016			2017			2016
	(Millions of dollars)
International Downstream Earnings*	$	1,174	$	542		$	2,192		$	1,771
___________________
* Includes foreign currency effects	$	15	$	(4	)	$	(27	)	$	(78	)

~~U.S.~~International downstream operations earned ~~$469 million~~$1.17 billion in ~~first~~third quarter 2017, compared with ~~earnings of $247~~$542 million a year earlier. The increase in earnings was largely due to higher gains on asset sales of $760 million, primarily from the $675 million gain on the sale of the company's Canadian refining and marketing assets. Higher operating expenses of $80 million and lower margins on refined product sales of $40 million were partially offsetting. Foreign currency effects had a favorable impact on earnings of $19 million between periods.

Earnings for the first nine months of 2017 were $2.19 billion, compared with $1.77 billion a year earlier. The increase in earnings was primarily due to ~~the absence~~higher gains on asset sales of ~~a first quarter 2016 asset impairment of $110 million, lower operating expenses of $80~~$370 million and higher margins on refined product sales of ~~$30~~$200 million.

~~Refinery crude oil input in~~ ~~first quarter2017~~ ~~decreased 5 percent to 912,000 barrels per day from the year-ago period. Refined product sales~~ Higher operating expenses of ~~1.15~~$120 million ~~barrels per day decreased 5 percent from first quarter 2016. Branded gasoline sales~~and lower shipping results of ~~511,000 barrels per day~~$80 million were ~~essentially unchanged from the 2016 period. Both refinery crude oil input and refined product sales were down due to divestment of the Hawaii refining and marketing assets.~~

Three Months Ended
March 31
2017 2016
(Millions of dollars)
International Downstream Earnings* $ 457
$ 488
___________________
* Includes foreign currency effects $ (46 ) $ (48 )

International downstream operations earned $457 million in first quarter 2017, compared with $488 million a year earlier. The decrease was primarily due to lower margins on refined product sales of $30 million.partially offsetting. Foreign currency effects ~~decreased~~had a favorable impact on earnings ~~by $46~~of $51 million ~~in first quarter 2017, compared with a decrease of $48 million a year earlier.~~between periods.

Refinery crude oil input of ~~753,000~~801,000 barrels per day in ~~first~~third quarter 2017 ~~decreased 42,000~~increased 11,000 barrels per day from the year-ago period mainly due to ~~planned turnaround activity~~crude unit optimizations and lower maintenance at the company's ~~refinery in Cape Town, South Africa.~~affiliate, Singapore Refining Company. For the first nine months of 2017, crude input was 760,000 barrels per day, down 3 percent from the year-ago period.

Total refined product sales of ~~1.45~~1.55 million barrels per day in ~~first~~third quarter 2017 ~~increased 1~~were up 6 percent from the year -ago period, primarily due to higher diesel and jet fuel sales. Total refined product sales for the first nine months of 2017 were up 2 percent from the year-ago ~~period due to higher gas oil and fuel oil sales, partially offset by lower gasoline sales.~~period.

All Other


	Three Months Ended March 31					Three Months Ended September 30						Nine Months Ended September 30
	2017		2016			2017			2016			2017			2016
	(Millions of dollars)					(Millions of dollars)
Earnings/(Charges)*	$	239	$	(1	)
Net Charges*						$	(351	)	$	(236	)	$	(710	)	$	(523	)
___________________
* Includes foreign currency effects	$	79	$	27		$	37		$	(9	)	$	117		$	(6	)

All Other consists of worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities and technology companies.

Net ~~earnings~~charges in ~~first~~third quarter2017 were ~~$239~~$351 million,, compared with ~~net charges of~~ $1$236 million a year earlier. The change between periods was mainly due to higher tax items and higher corporate charges. Partially offsetting was lower ~~employee expenses and favorable corporate tax items.~~interest expenses. Foreign currency effects ~~increased earnings~~decreased net charges by ~~$79~~$46 million between periods.

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Net charges for the first ~~three~~nine months of 2017, were $710 million, compared with $523 million a ~~benefit~~year earlier. The change between periods was mainly due to higher tax items, an impairment of ~~$27~~an asset, and higher corporate charges, partially offset by lower employee expense. Foreign currency effects decreased net charges by $123 million ~~in the 2016 period.~~ between periods.

Consolidated Statement of Income

Explanations of variations between periods for selected income statement categories are provided below:

Three Months Ended
March 31
2017 2016
(Millions of dollars)
Sales and other operating revenues $ 31,524
$ 23,070



	Three Months Ended September 30				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)
Sales and other operating revenues	$	33,892	$	29,159	$	98,293	$	80,073

Sales and other operating revenues increased ~~$8.5~~$4.7 billion infor the ~~first quarter, primarily~~quarterly period mainly due to higher refined product and crude oil ~~and~~prices, higher refined product ~~prices.~~

~~Table of Contents~~

volumes, and higher natural gas prices and volumes. Sales and other operating revenues increased $18.2 billion for the nine-month period mainly due to higher refined product and crude oil prices, higher crude oil volumes, and higher natural gas prices and volumes.

Three Months Ended
March 31
2017 2016
(Millions of dollars)
Income from equity affiliates $ 1,150
$ 576



	Three Months Ended September 30				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)
Income from equity affiliates	$	1,036	$	555	$	3,502	$	1,883

Income from equity affiliates in the quarterly period increased mainly due to higher upstream-related earnings from Tengizchevroil in ~~Kazakhstan, Angola LNG, and Petropiar and Petroboscan~~Kazakhstan. Income from equity affiliates in ~~Venezuela, partially offset by lower downstream-related~~the nine-month period increased mainly due to higher upstream-related earnings from ~~GS Caltex~~Tengizchevroil in ~~South Korea.~~Kazakhstan and Angola LNG.

Three Months Ended
March 31
2017 2016
(Millions of dollars)
Other income $ 747
$ (93 )



	Three Months Ended September 30				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)
Other income	$	1,277	$	426	$	2,311	$	1,019

Other income for the ~~first quarter~~quarterly and nine-month periods increased due to higher gains on asset ~~sales and a favorable swing in foreign currency effects.~~sales.

Three Months Ended
March 31
2017 2016
(Millions of dollars)
Purchased crude oil and products $ 17,506
$ 11,225



	Three Months Ended September 30				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)
Purchased crude oil and products	$	18,776	$	15,842	$	54,607	$	42,345

Purchases increased ~~$6.3~~$2.9 billion infor the ~~first quarter,~~quarterly period primarily due to higher refined product and crude oil prices, and higher crude oil and refined product volumes. The nine-month period increased $12.3 billion primarily due to higher crude oil and refined product prices, higher refined product and crude oil volumes, and higher natural gas prices.

Three Months Ended
March 31
2017 2016
(Millions of dollars)
Operating, selling, general and
administrative expenses
$ 5,526
$ 6,402



	Three Months Ended September 30				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)
Operating, selling, general and administrative expenses	$	6,175	$	5,775	$	17,354	$	18,264

Operating, selling, general and administrative expenses ~~decreased $876~~increased $400 million between quarterly periods ~~mostly~~due to higher services and fees, employee, environmental, and fuel expenses.

Expenses decreased $910 million between nine-month periods primarily due to lower employee, non-operated joint venture and transportation expenses, partially offset by higher fuel expenses.

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Three Months Ended
March 31
2017 2016
(Millions of dollars)
Exploration expenses $ 144
$ 370



	Three Months Ended September 30				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)
Exploration expenses	$	239	$	258	$	508	$	842

The decrease in exploration expenses for the ~~first quarter~~quarterly period and nine-month periods was ~~mostly~~primarily due to lower charges for well write-offs.

Three Months Ended
March 31
2017 2016
(Millions of dollars)
Depreciation, depletion and
amortization
$ 4,194
$ 4,403



	Three Months Ended September 30				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)
Depreciation, depletion and amortization	$	5,109	$	4,130	$	14,614	$	15,254

Depreciation, depletion and amortization expenses in third quarter 2017 increased mainly due to higher production levels for certain oil and gas producing fields, an asset write-off, and catch-up depreciation for the ~~first quarter~~Bangladesh operations that the company no longer intends to sell, partially offset by lower depreciation rates for certain oil and gas producing fields. The nine-month period decreased mainly due to lower impairment expenses for certain oil and gas producing properties, and the absence of a 2016 impairment of a downstream asset, ~~and lower depreciation rates for certain oil and gas producing fields,~~ partially offset by higher production levels for certain oil and gas producing ~~fields.~~

~~Table of Contents~~

fields, an asset write-off, and catch-up depreciation for the Bangladesh operations that the company no longer intends to sell.

Three Months Ended
March 31
2017 2016
(Millions of dollars)
Taxes other than on income $ 2,871
$ 2,864



	Three Months Ended September 30				Nine Months Ended September 30
	2017		2016		2017		2016
	(Millions of dollars)
Taxes other than on income	$	3,213	$	2,962	$	9,149	$	8,799

Taxes other than on income ~~were relatively flat between periods.~~increased in third quarter 2017 primarily due to higher crude oil, refined product and natural gas sales, higher duties, and higher production.

Taxes other than on income increased in the nine-month period primarily due to higher duties, higher crude oil, refined product and natural gas sales, and higher production.

Three Months Ended
March 31
2017 2016
(Millions of dollars)
Income tax expense $ 430
$ (1,004 )



	Three Months Ended September 30					Nine Months Ended September 30
	2017		2016			2017		2016
	(Millions of dollars)
Income tax expense (benefit)	$	672	$	(192	)	$	1,589	$	(1,803	)

The increase in income tax expense ~~in 2017~~between quarterly periods of ~~$1.43 billion~~$864 million is consistent with the increase in total income ~~before-tax~~before tax for the company of ~~$4.84~~$1.55 billion. U.S. losses before tax decreased from a loss of $480 million in third quarter 2016 to a loss of $211 million in 2017. The lower losses were primarily driven by the effect of higher crude oil prices. The decrease in losses had a direct impact on the company’s U.S. income tax benefit, resulting in a decrease in benefit of $111 million between year-over-year periods, from a tax benefit of $416 million in 2016 to a tax benefit of $305 million in 2017. International income before tax increased from ~~a loss of $1.64~~$1.59 billion in 2016 to ~~income of $237 million~~$2.87 billion in 2017. This $1.28 billion increase ~~in income~~ was primarily driven by the effect of higher crude oil prices. The higher crude prices primarily drove the $753 million increase in international income tax expense between year-over-year periods, from $224 million in 2016 to $977 million in 2017.

The increase in income tax expense for the first nine months of 2017 of $3.39 billion is consistent with the increase in total income before tax for the company of $10.41 billion. U.S. losses before tax decreased from a loss of $3.88 billion in 2016 to a loss of $66 million in 2017. This decrease in losses was primarily driven by the effect of higher crude oil prices. The decrease in losses had a direct impact on the company’s U.S. income tax cost, resulting in a decrease in tax benefit of ~~$482 million~~$1.52 billion between year-over-year periods, from ~~a tax benefit of $870 million~~$2.07 billion in 2016 to ~~a tax benefit of $388~~$549 million in 2017. ~~Contributing to the result were U.S. tax adjustments.~~ International income before tax increased from ~~a loss of $67 million~~$1.20 billion in 2016 to ~~income of $2.89~~$7.81 billion in 2017. This ~~$2.96~~$6.61 billion increase was primarily driven by the effect of higher crude oil prices and ~~the gain~~gains on ~~the sale of the company’s geothermal assets~~asset sales primarily in ~~Indonesia.~~Indonesia and Canada. The higher crude prices primarily drove the ~~$952 million~~$1.87 billion increase in international income tax expense between year-over-year periods, from ~~a benefit of $134~~$264 million in 2016 to ~~a cost of $818 million~~$2.14 billion in 2017.

Refer also to the discussion of the effective income tax rate in Note 11 on pages 14 and 15.

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Selected Operating Data

The following table presents a comparison of selected operating data:

Selected Operating Data ⁽¹⁾⁽²⁾


	Three Months Ended March 31				Three Months Ended September 30				Nine Months Ended September 30
	2017		2016		2017		2016		2017		2016
U.S. Upstream
Net crude oil and natural gas liquids production (MBPD)	504		490		525		519		520		503
Net natural gas production (MMCFPD)⁽³⁾	1,006		1,266		932		1,077		988		1,144
Net oil-equivalent production (MBOEPD)	672		701		681		698		684		694
Sales of natural gas (MMCFPD)	3,142		3,808		3,455		3,263		3,288		3,408
Sales of natural gas liquids (MBPD)	29		24		37		37		34		29
Revenue from net production
Liquids ($/Bbl)	$	44.83	$	26.49	$	41.83	$	36.88	$	42.65	$	33.16
Natural gas ($/MCF)	$	2.39	$	1.32	$	1.80	$	1.89	$	2.17	$	1.47
International Upstream
Net crude oil and natural gas liquids production (MBPD)⁽⁴⁾	1,204		1,291		1,194		1,142		1,206		1,207
Net natural gas production (MMCFPD)⁽³⁾	4,801		4,044		5,053		4,036		5,001		4,009
Net oil-equivalent production (MBOEPD)⁽⁴⁾	2,004		1,965		2,036		1,815		2,040		1,875
Sales of natural gas (MMCFPD)	4,933		4,558		4,978		4,306		5,018		4,455
Sales of natural gas liquids (MBPD)	23		24		28		21		29		23
Revenue from liftings
Liquids ($/Bbl)	$	48.56	$	29.14	$	47.81	$	41.08	$	47.07	$	36.64
Natural gas ($/MCF)	$	4.36	$	3.91	$	4.76	$	4.18	$	4.50	$	4.01
U.S. and International Upstream
Total net oil-equivalent production (MBOEPD)⁽⁴⁾	2,676		2,666		2,717		2,513		2,724		2,569
U.S. Downstream
Gasoline sales (MBPD)⁽⁵⁾	584		616		649		653		629		638
Other refined product sales (MBPD)	569		594		576		591		577		601
Total refined product sales (MBPD)	1,153		1,210		1,225		1,244		1,206		1,239
Sales of natural gas liquids (MBPD)	106		105		100		127		108		116
Refinery input (MBPD)	912		957		931		970		924		960
International Downstream
Gasoline sales (MBPD)⁽⁵⁾	331		360		352		378		339		361
Other refined product sales (MBPD)	753		707		835		700		785		716
Share of affiliate sales (MBPD)	361		369		369		391		360		374
Total refined product sales (MBPD)	1,445		1,436		1,556		1,469		1,484		1,451
Sales of natural gas liquids (MBPD)	65		64		62		46		65		59
Refinery input (MBPD)	753		795		801		790		760		784
_____________________
⁽¹⁾ Includes company share of equity affiliates.
⁽²⁾ MBPD — thousands of barrels per day; MMCFPD — millions of cubic feet per day; Bbl — Barrel; MCF — thousands of cubic feet; oil-equivalent gas conversion ratio is 6,000 cubic feet of natural gas = 1 barrel of crude oil; MBOEPD — thousands of barrels of oil-equivalent per day.	⁽²⁾ MBPD — thousands of barrels per day; MMCFPD — millions of cubic feet per day; Bbl — Barrel; MCF — thousands of cubic feet; oil-equivalent gas conversion ratio is 6,000 cubic feet of natural gas = 1 barrel of crude oil; MBOEPD — thousands of barrels of oil-equivalent per day.				⁽²⁾ MBPD — thousands of barrels per day; MMCFPD — millions of cubic feet per day; Bbl — Barrel; MCF — thousands of cubic feet; oil-equivalent gas conversion ratio is 6,000 cubic feet of natural gas = 1 barrel of crude oil; MBOEPD — thousands of barrels of oil-equivalent per day.
⁽³⁾ Includes natural gas consumed in operations (MMCFPD):					⁽³⁾ Includes natural gas consumed in operations (MMCFPD):
United States	37		67		34		46		37		61
International	512		428		545		435		523		431
⁽⁴⁾ Includes net production of synthetic oil:
Canada	51		49		56		58		52		50
Venezuela affiliate	29		27		29		29		29		28
⁽⁵⁾ Includes branded and unbranded gasoline.

Table of Contents

Liquidity and Capital Resources

Cash, cash equivalents and marketable securities totaled $~~7.0~~6.7 billion at ~~March 31,~~September 30, 2017 and $7.0 billion at year-end 2016. Cash provided by operating activities in the first ~~three~~nine months of 2017 was ~~$3.9~~$14.3 billion, compared with $~~1.1~~9.0 billion in the year-ago period, reflecting higher crude oil prices. Cash capital and exploratory expenditures totaled ~~$3.5~~$10.1 billion in the first ~~three~~nine months of 2017, down ~~$2.2~~$4.3 billion from the year-ago period, reflecting lower activity. Cash provided by investing activities included proceeds and deposits related to asset sales of ~~$2.1~~$4.9 billion in the first ~~three~~nine months of 2017, compared to ~~$0.1~~$2.2 billion in the year ago period.

Dividends The company paid dividends of ~~$2.0~~$6.1 billion to common shareholders during the first ~~three~~nine months of ~~2017~~.2017. In ~~April~~October 2017, the company declared a quarterly dividend of $1.08 per common share, payable in ~~June~~December 2017.

Debt and Capital Lease Obligations Chevron’s total debt and capital lease obligations were $~~45.3~~42.0 billion at ~~March 31,~~September 30, 2017, down from $46.1 billion at December 31, 2016.

The company’s primary financing source for working capital needs is its commercial paper program. The outstanding balance for the company's commercial paper program at ~~March 31,~~September 30, 2017 was ~~$6.5~~$3.2 billion. The company’s debt and capital lease obligations due within one year, consisting primarily of commercial paper, redeemable long-term obligations and the current portion of long-term debt, totaled ~~$17.3~~$16.7 billion at ~~March 31,~~September 30, 2017, and $19.8 billion at December 31, 2016. Of these amounts, $9.0 billion was reclassified to long-term at both ~~March 31,~~September 30, 2017, and December 31, 2016. At ~~March 31,~~September 30, 2017, settlement of these obligations was not expected to require the use of working capital within one year, as the company had the intent and the ability, as evidenced by committed credit facilities, to refinance them on a long-term basis.

At ~~March 31,~~September 30, 2017, the company had $9.0 billion in committed credit facilities with various major banks that enable the refinancing of short-term obligations on a long-term basis. The credit facilities consist of a 364-day facility which enables borrowing of up to $6.9 billion and allows the company to convert any amounts outstanding into a term loan for a period of up to one year, as well as a $2.1 billion five-year facility expiring in December 2020. These facilities support commercial paper borrowing and can also be used for general corporate purposes. The company’s practice has been to continually replace expiring commitments with new commitments on substantially the same terms, maintaining levels management believes appropriate. Any borrowings under the facilities would be unsecured indebtedness at interest rates based on the London Interbank Offered Rate or an average of base lending rates published by specified banks and on terms reflecting the company’s strong credit rating. No borrowings were outstanding under these facilities at ~~March 31,~~September 30, 2017. In addition, the company has an automatic shelf registration statement that expires in August 2018 for an unspecified amount of nonconvertible debt securities issued or guaranteed by the company.

The major debt rating agencies routinely evaluate the company’s debt, and the company’s cost of borrowing can increase or decrease depending on these debt ratings. The company has outstanding public bonds issued by Chevron Corporation and Texaco Capital Inc. All of these securities are the obligations of, or guaranteed by, Chevron Corporation and are rated AA- by Standard and Poor’s Corporation and Aa2 by Moody’s Investors Service. The company’s U.S. commercial paper is rated A-1+ by Standard and Poor’s and P-1 by Moody’s. All of these ratings denote high-quality, investment-grade securities.

The company’s future debt level is dependent primarily on results of operations, the capital program and cash that may be generated from asset dispositions. Based on its high-quality debt ratings, the company believes that it has substantial borrowing capacity to meet unanticipated cash requirements. During extended periods of low prices for crude oil and natural gas and narrow margins for refined products and commodity chemicals, the company can also modify capital spending plans to provide flexibility to continue paying the common stock dividend and also remain committed to retaining the company’s high-quality debt ratings.

Common Share Repurchase Program In July 2010, the Board of Directors approved an ongoing share repurchase program with no set term or monetary limits. No shares were acquired under the program in 2015, 2016 or through the first ~~three~~nine months of 2017, and the company does not plan to acquire any shares under the program for the remainder of the year. From the inception of the program through 2014, the company had purchased 180.9 million shares for $20.0 billion.

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Noncontrolling Interests The company had noncontrolling interests of $1.2 billion at both ~~March 31,~~September 30, 2017,, and December 31, ~~2016. There were no distributions~~2016. Distributions to noncontrolling interests totaled $66 million during the first ~~three~~nine months of 2017 orcompared to $57 million for the same period in 2016.

Current Ratio Current assets divided by current liabilities, which indicates the company’s ability to repay its short-term liabilities with short-term assets. The current ratio was 1.0 at ~~March 31,~~September 30, 2017, and 0.9 at December 31, 2016, respectively. The current ratio is adversely affected by the fact that Chevron’s inventories are valued on a last-in, first-out basis. At ~~March 31,~~September 30, 2017, the book value of inventory was lower than replacement cost.

Debt Ratio Total debt as a percentage of total debt plus Chevron Corporation Stockholders’ Equity, which indicates the company’s leverage. This ratio was ~~23.6~~22.2 percent at ~~March 31,~~September 30, 2017, and 24.1 percent at year-end 2016.

Pension Obligations Information related to pension plan contributions is included on page 1314 in Note 10 to the Consolidated Financial Statements.

Capital and Exploratory Expenditures Total expenditures, including the company’s share of spending by affiliates, were $~~4.4~~13.4 billion in the first ~~three~~nine months of 2017, compared with $~~6.5~~17.2 billion in the corresponding 2016 period. The amounts included the company’s share of affiliates’ expenditures of $~~0.9~~3.3 billion and ~~$0.8~~$2.7 billion in the 2017 and 2016 periods, respectively, which did not require cash outlays by the company. Expenditures for upstream projects in the first ~~three~~nine months of 2017 were $~~4.0~~11.9 billion, representing 9089 percent of the companywide total.

Capital and Exploratory Expenditures by Major Operating Area


		Three Months Ended March 31				Three Months Ended September 30				Nine Months Ended September 30
		2017		2016		2017		2016		2017		2016
	(Millions of dollars)					(Millions of dollars)
United States
Upstream		$	1,051	$	1,276	$	1,201	$	990	$	3,406	$	3,470
Downstream		321		421		367		357		1,049		1,110
All Other		34		22		63		62		132		137
Total United States		1,406		1,719		1,631		1,409		4,587		4,717
International
Upstream		2,916		4,690		2,715		3,649		8,501		12,157
Downstream		69		59		110		115		297		290
All Other		1		1		—		2		1		3
Total International		2,986		4,750		2,825		3,766		8,799		12,450
Worldwide		$	4,392	$	6,469	$	4,456	$	5,175	$	13,386	$	17,167

Contingencies and Significant Litigation

MTBE Information related to methyl tertiary butyl ether (MTBE) matters is included on page 15 in Note 13 to the Consolidated Financial Statements under the heading “MTBE.”

Ecuador Information related to Ecuador matters is included beginning on page 15 in Note 13 to the Consolidated Financial Statements under the heading “Ecuador.”

Income Taxes Information related to income tax contingencies is included on pages 14 and 15 in Note 11 and page 1920 in Note 14 to the Consolidated Financial Statements under the heading “Income Taxes.”

Guarantees Information related to the company’s guarantees is included on page 1920 in Note 14 to the Consolidated Financial Statements under the heading “Guarantees.”

Indemnifications Information related to indemnifications is included on ~~pages 19 and~~page 20 in Note 14 to the Consolidated Financial Statements under the heading “Indemnifications.”

Off-Balance-Sheet Obligations Information related to the company’s off-balance-sheet obligations is included on page 20 in Note 14 to the Consolidated Financial Statements under the heading “Off-Balance-Sheet Obligations.”

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Environmental Information related to environmental matters is included on ~~page~~pages 20 and 21 in Note 14 to the Consolidated Financial Statements under the heading “Environmental.”

Other Contingencies Information related to the company’s other contingencies ~~is included~~begins on page 2021 in Note 14 to the Consolidated Financial Statements under the heading “Other Contingencies.”

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Item 3.	Quantitative and Qualitative Disclosures About Market Risk

Information about market risks for the three months ended ~~March 31,~~September 30, 2017, does not differ materially from that discussed under Item 7A of Chevron’s 2016 Annual Report on Form 10-K.


Item 4.	Controls and Procedures

(a) Evaluation of disclosure controls and procedures

The company’s management has evaluated, with the participation of the Chief Executive Officer and Chief Financial Officer, the effectiveness of the company’s disclosure controls and procedures (as defined in Rule 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) as of the end of the period covered by this report. Based on this evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the company’s disclosure controls and procedures were effective as of ~~March 31,~~September 30, 2017.

(b) Changes in internal control over financial reporting

During the quarter ended ~~March 31,~~September 30, 2017, there were no changes in the company’s internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, the company’s internal control over financial reporting.

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PART II

OTHER INFORMATION


Item 1.	Legal Proceedings

Governmental Proceedings ~~On November 18, 2016,~~As initially disclosed in the Annual Report on Form 10-K for the year ended December 31, 2013, on August 6, 2012, a piping failure and fire occurred at the Chevron ~~received an Administrative Order (AO) from~~refinery in Richmond, California. Various federal, state, and local agencies initiated investigations as a result of the ~~U.S.~~incident. The California Division of Occupational Safety and Health (“Cal/OSHA”) issued citations related to the incident in January 2013. Chevron and Cal/OSHA resolved these citations in July 2017 through a settlement agreement that included a civil penalty of $1.01 million. The United States Environmental Protection Agency ~~(EPA) alleging noncompliance with~~(“EPA”) issued alleged findings of violation related to the ~~water permit that governed conveyances of captured groundwater and spring water from the former Questa mine located in New Mexico~~incident on December 17, 2013, pursuant to its ~~associated tailing facility.~~authority under the Clean Air Act Risk Management Plan program (“RMP”). Following the Richmond incident, EPA also conducted RMP inspections at Chevron’s El Segundo, California; Pascagoula, Mississippi; Kapolei, Hawaii; and Salt Lake City, Utah refineries. With the participation of the United States Department of Justice, Chevron ~~is in negotiations with~~and EPA ~~regarding this matter.~~are negotiating a potential combined resolution that may include all of EPA’s alleged findings of violation related to the Richmond incident and subsequent RMP inspections. Resolution of ~~this matter~~those alleged findings of violation may result in the payment of a civil ~~penalties~~penalty of $100,000 or more.

On August 3, 2017, Chevron received a Notice of Intent to File an Administrative Complaint from the United States Environmental Protection Agency in connection with certain waste matters at the Kapolei, Hawaii Refinery during the period of time that the facility was owned and operated by Chevron. Chevron is evaluating the allegations stated in the Notice. Resolution of these matters may result in the payment of a civil penalty of $100,000 or more.

Other Proceedings Information related to legal proceedings, including Ecuador, is included beginning on page 15 in Note 13 to the Consolidated Financial Statements.

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Item 1A.	Risk Factors

Chevron is a global energy company with a diversified business portfolio, a strong balance sheet, and a history of generating sufficient cash to fund capital and exploratory expenditures and to pay dividends. Nevertheless, some inherent risks could materially impact the company’s financial results of operations or financial condition.

Information about risk factors for the three months ended ~~March 31,~~September 30, 2017, does not differ materially from that set forth under the heading “Risk Factors” on pages 20 through 22 of the company’s 2016 Annual Report on Form 10-K.


Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds

CHEVRON CORPORATION

ISSUER PURCHASES OF EQUITY SECURITIES

Period
Total Number
Of Shares
Purchased ⁽¹⁾⁽²⁾

Average
Price Paid
per Share

Total Number of
Shares Purchased as
Part of Publicly
Announced Program

Maximum
Number of Shares
that May Yet Be
Purchased Under
the Program ⁽²⁾
Jan. 1 – Jan. 31, 2017 9,852
$ 117.84
—

Feb. 1 – Feb. 28, 2017 —
—
—

Mar. 1 – Mar. 31, 2017 —
—
—

Total 9,852
$ 117.84
—



Period	Total Number Of Shares Purchased ⁽¹⁾⁽²⁾	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Program	Maximum Number of Shares that May Yet Be Purchased Under the Program ⁽²⁾
July 1 – July 31, 2017	26	$	106.28	—
August 1 – August 31, 2017	—			—
September 1 – September 30, 2017	—			—
Total	26	$	106.28	—

~~_______________________~~


⁽¹⁾	Includes common shares repurchased from company employees and directors for required personal income tax withholdings on the exercise of the stock options and shares delivered or attested to in satisfaction of the exercise price by holders of employee and director stock options. The options were issued to and exercised by management under Chevron long-term incentive plans.

⁽²⁾

In July 2010, the Board of Directors approved an ongoing share repurchase program with no set term or monetary limits, under which common shares would be acquired by the company at prevailing prices, as permitted by securities laws and other legal requirements and subject to market conditions and other factors. From inception of the program through 2014, the company had purchased 180,886,291 shares under this program (some pursuant to Rule 10b5-1 plan and some pursuant to accelerated share repurchase plans) for $20.0 billion at an average price of approximately $111 per share. No shares were acquired under the program in 2015 or 2016 or through the first ~~three~~nine months of 2017, and the company does not plan to acquire any shares under the program for the remainder of the year.


Item 5.	Other Information

Rule 10b5-1 Plan Elections

John S. Watson, Chairman and Chief Executive Officer, entered into a pre-arranged stock trading plan in August 2017. Mr. Watson’s plan provides for the potential exercise of vested, soon-to-expire stock options and the associated sale of up to 112,000 shares of Chevron common stock during the period between Chevron’s public release of earnings for the quarter and year ended December 31, 2017, and March 2018.

Pierre R. Breber, Executive Vice President, Downstream & Chemicals, also entered into a pre-arranged stock trading plan in August 2017. Mr. Breber’s plan provides for the potential exercise of vested stock options and the associated sale of up to 46,500 shares of Chevron common stock between November 2017 and July 2018.

Both trading plans were entered into during an open insider trading window and are intended to satisfy Rule 10b5-1(c) of the Securities Exchange Act of 1934, as amended, and Chevron’s policies regarding transactions in Chevron securities.

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Item 6.	Exhibits

Exhibit Index



Exhibit Number		Description

(4)		Pursuant to the Instructions to Exhibits, certain instruments defining the rights of holders of long-term debt securities of the company and its consolidated subsidiaries are not filed because the total amount of securities authorized under any such instrument does not exceed 10 percent of the total assets of the company and its subsidiaries on a consolidated basis. A copy of such instrument will be furnished to the Securities and Exchange Commission upon request.
(10.1)	~~Form of Non-Qualified Stock Options Award Agreement under the Long-Term Incentive Plan of~~	Chevron Corporation ~~filed~~ESIP Restoration Plan, Amended and Restated as ~~Exhibit 10.1 to Chevron Corporation’s Current Report on Form 8-K, filed~~of January ~~30, 2017, and incorporated herein by reference.~~
~~(10.2)~~	Form of Performance Share Award Agreement under the Long-Term Incentive Plan of Chevron Corporation, filed as Exhibit 10.2 to Chevron Corporation’s Current Report on Form 8-K, filed January 30, 2017, and incorporated herein by reference.
~~(10.3)~~	Form of Standard Restricted Stock Unit Award Agreement under the Long-Term Incentive Plan of Chevron Corporation, filed as Exhibit 10.3 to Chevron Corporation’s Current Report on Form 8-K, filed January 30, 2017, and incorporated herein by reference.
~~(10.4)~~	Form of Special Restricted Stock Unit Award Agreement under the Long-Term Incentive Plan of Chevron Corporation, filed as Exhibit 10.4 to Chevron Corporation’s Current Report on Form 8-K, filed January 30, 2017, and incorporated herein by reference.1, 2018
(12.1)		Computation of Ratio of Earnings to Fixed Charges
(31.1)		Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Executive Officer
(31.2)		Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Financial Officer
(32.1)		Rule 13a-14(b)/15d-14(b) Certification by the company’s Chief Executive Officer
(32.2)		Rule 13a-14(b)/15d-14(b) Certification by the company’s Chief Financial Officer
(101.INS)		XBRL Instance Document
(101.SCH)		XBRL Schema Document
(101.CAL)		XBRL Calculation Linkbase Document
(101.DEF)		XBRL Definition Linkbase Document
(101.LAB)		XBRL Label Linkbase Document
(101.PRE)		XBRL Presentation Linkbase Document

Attached as Exhibit 101 to this report are documents formatted in XBRL (Extensible Business Reporting Language). The financial information contained in the XBRL-related documents is “unaudited” or “unreviewed.”

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SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



	CHEVRON CORPORATION (REGISTRANT)


	/S/ JEANETTE L. OURADA
	Jeanette L. Ourada, Vice President and Comptroller (Principal Accounting Officer and Duly Authorized Officer)

Date: ~~May 4,~~November 2, 2017

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~~EXHIBIT INDEX~~



~~Exhibit~~ ~~Number~~	~~Description~~
~~(4)~~	Pursuant to the Instructions to Exhibits, certain instruments defining the rights of holders of long-term debt securities of the company and its consolidated subsidiaries are not filed because the total amount of securities authorized under any such instrument does not exceed 10 percent of the total assets of the company and its subsidiaries on a consolidated basis. A copy of such instrument will be furnished to the Securities and Exchange Commission upon request.
~~(10.1)~~	Form of Non-Qualified Stock Options Award Agreement under the Long-Term Incentive Plan of Chevron Corporation, filed as Exhibit 10.1 to Chevron Corporation’s Current Report on Form 8-K, filed January 30, 2017, and incorporated herein by reference.
~~(10.2)~~	Form of Performance Share Award Agreement under the Long-Term Incentive Plan of Chevron Corporation, filed as Exhibit 10.2 to Chevron Corporation’s Current Report on Form 8-K, filed January 30, 2017, and incorporated herein by reference.
~~(10.3)~~	Form of Standard Restricted Stock Unit Award Agreement under the Long-Term Incentive Plan of Chevron Corporation, filed as Exhibit 10.3 to Chevron Corporation’s Current Report on Form 8-K, filed January 30, 2017, and incorporated herein by reference.
~~(10.4)~~	Form of Special Restricted Stock Unit Award Agreement under the Long-Term Incentive Plan of Chevron Corporation, filed as Exhibit 10.4 to Chevron Corporation’s Current Report on Form 8-K, filed January 30, 2017, and incorporated herein by reference.
(12.1)*	~~Computation of Ratio of Earnings to Fixed Charges~~
(31.1)*	~~Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Executive Officer~~
(31.2)*	~~Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Financial Officer~~
(32.1)*	~~Rule 13a-14(b)/15d-14(b) Certification by the company’s Chief Executive Officer~~
(32.2)*	~~Rule 13a-14(b)/15d-14(b) Certification by the company’s Chief Financial Officer~~
(101.INS)*	~~XBRL Instance Document~~
(101.SCH)*	~~XBRL Schema Document~~
(101.CAL)*	~~XBRL Calculation Linkbase Document~~
(101.DEF)*	~~XBRL Definition Linkbase Document~~
(101.LAB)*	~~XBRL Label Linkbase Document~~
(101.PRE)*	~~XBRL Presentation Linkbase Document~~

~~_________________________~~

* Filed herewith.

Copies of any of the above exhibits not contained herein are available to any security holder upon written request to the Corporate Governance Department, Chevron Corporation, 6001 Bollinger Canyon Road, San Ramon, California 94583-2324.