.

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

☑    QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2020

or

☐    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)

6001 Bollinger Canyon Road

Delaware

94-0890210

San Ramon,

California

94583-2324

(State or other jurisdiction of incorporation or organization)

(I.R.S. Employer Identification No.)

(Address of principal executive offices) (Zip Code)

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

NONE

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

Securities registered pursuant to Section 12(b) of the Act:

Title of each class

Trading Symbol

Name of each exchange on which registered

Common stock, par value $.75 per share

CVX

New York Stock Exchange

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  ☑        No  ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 such files).    Yes  ☑        No  ☐

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

☑

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

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. ☐ 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).     Yes  ☐       No  ☑

There were 1,867,323,448 shares of the Company’s common stock outstanding on September 30, 2020.

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Table of Contents

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 September 30, 2020, and 2019			3
			Consolidated Statement of Comprehensive Income for the Three and Nine Months Ended September 30, 2020, and 2019			4
			Consolidated Balance Sheet at September 30, 2020, and December 31, 2019			5
			Consolidated Statement of Cash Flows for the Nine Months Ended September 30, 2020, and 2019			6
			Consolidated Statement of Equity for the Three and Nine Months Ended September 30, 2020, and 2019			7
			Notes to Consolidated Financial Statements			8
Item 2.			Management’s Discussion and Analysis of Financial Condition and Results of Operations			24
Item 3.			Quantitative and Qualitative Disclosures About Market Risk			40
Item 4.			Controls and Procedures			40
PART II OTHER INFORMATION
Item 1.			Legal Proceedings			40
Item 1A.			Risk Factors			41
Item 2.			Unregistered Sales of Equity Securities and Use of Proceeds			43
Item 5.			Other Information			43
Item 6.			Exhibits			44
Signature						45

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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,” “will,” “budgets,” “outlook,” “trends,” “guidance,” “focus,” “on schedule,” “on track,” “is slated,” “goals,” “objectives,” “strategies,” “opportunities,” “poised,” “potential” 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 and demand for our products, and production curtailments due to market conditions; crude oil production quotas or other actions that might be imposed by the Organization of Petroleum Exporting Countries and other producing countries; public health crises, such as pandemics (including coronavirus (COVID-19)) and epidemics, and any related government policies and actions; changing economic, regulatory and political environments in the various countries in which the company operates; general domestic and international economic and political conditions; changing refining, marketing and chemicals margins; the company’s ability to realize anticipated cost savings, expenditure reductions and efficiencies associated with enterprise transformation initiatives; 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 during the COVID-19 pandemic; 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, terrorist acts, or other natural or human causes beyond the company’s control; 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 pending or future litigation; the company’s ability to successfully integrate the operations of Chevron and Noble Energy and achieve the anticipated benefits from the acquisition of Noble Energy; the company’s future acquisitions or dispositions 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, tariffs, sanctions, 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 receipt of required Board authorizations to pay future dividends; 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 18 through 21 of the company’s 2019 Annual Report on Form 10-K, on pages 41 to 42 of this report and in subsequent filings with the U.S. Securities and Exchange Commission. Other unpredictable or unknown factors not discussed in this report could also have material adverse effects on forward-looking statements.

2

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Table of Contents

PART I.

FINANCIAL INFORMATION

 

Item 1.Consolidated Financial Statements

CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF INCOME

(Unaudited)

 

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars, except per-share amounts)
Revenues and Other Income
Sales and other operating revenues			$	23,997					$	34,779					$	69,628					$	105,291
Income (loss) from equity affiliates			510						1,172						(1,040)						3,430
Other income (loss)			(56)						165						858						1,445
Total Revenues and Other Income			24,451						36,116						69,446						110,166
Costs and Other Deductions
Purchased crude oil and products			13,448						19,882						37,101						60,420
Operating expenses			4,604						5,325						15,425						15,398
Selling, general and administrative expenses			832						954						3,084						3,014
Exploration expenses			117						168						1,170						498
Depreciation, depletion and amortization			4,017						4,361						15,022						12,789
Taxes other than on income			1,091						1,059						3,223						3,167
Interest and debt expense			164						197						498						620
Other components of net periodic benefit costs			222						121						419						319
Total Costs and Other Deductions			24,495						32,067						75,942						96,225
Income (Loss) Before Income Tax Expense			(44)						4,049						(6,496)						13,941
Income Tax Expense (Benefit)			165						1,469						(1,591)						4,429
Net Income (Loss)			(209)						2,580						(4,905)						9,512
Less: Net income (loss) attributable to noncontrolling interests			(2)						—						(27)						(22)
Net Income (Loss) Attributable to Chevron Corporation			$	(207)					$	2,580					$	(4,878)					$	9,534
Per Share of Common Stock
Net Income (Loss) Attributable to Chevron Corporation
- Basic			$	(0.12)					$	1.38					$	(2.63)					$	5.06
- Diluted			$	(0.12)					$	1.36					$	(2.63)					$	5.02
Weighted Average Number of Shares Outstanding (000s)
- Basic			1,853,533						1,880,607						1,856,363						1,885,931
- Diluted			1,853,533						1,893,928						1,856,363						1,899,193

See accompanying notes to consolidated financial statements.

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CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

(Unaudited)

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
Net Income (Loss)			$	(209)					$	2,580					$	(4,905)					$	9,512
Currency translation adjustment			17						(33)						5						(32)
Unrealized holding gain (loss) on securities
Net gain (loss) arising during period			(1)						2						(5)						2
Derivatives
Net derivatives loss on hedge transactions			—						—						—						(1)
Reclassification to net income of net realized gain			—						—						—						—
Income taxes on derivatives transactions			—						3						—						3
Total			—						3						—						2
Defined benefit plans
Actuarial gain (loss)
Amortization to net income of net actuarial loss and settlements			293						150						628						400
Actuarial gain (loss) arising during period			—						—						—						(4)
Prior service credits (cost)
Amortization to net income of net prior service costs and curtailments			(5)						(4)						(13)						(11)
Prior service (costs) credits arising during period			—						—						—						1
Defined benefit plans sponsored by equity affiliates - benefit (cost)			5						3						14						8
Income (taxes) benefit on defined benefit plans			(66)						(33)						(146)						(91)
Total			227						116						483						303
Other Comprehensive Gain (Loss), Net of Tax			243						88						483						275
Comprehensive Income (Loss)			34						2,668						(4,422)						9,787
Comprehensive loss (income) attributable to noncontrolling interests			2						—						27						22
Comprehensive Income (Loss) Attributable to Chevron Corporation			$	36					$	2,668					$	(4,395)					$	9,809

See accompanying notes to consolidated financial statements.

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CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEET

(Unaudited)

						At September 30, 2020						At December 31, 2019
						(Millions of dollars)
Assets
Cash and cash equivalents						$	6,866					$	5,686
Marketable securities						28						63
Accounts and notes receivable, net						9,722						13,325
Inventories:
Crude oil and petroleum products						3,588						3,722
Chemicals						409						492
Materials, supplies and other						1,684						1,634
Total inventories						5,681						5,848
Prepaid expenses and other current assets						2,506						3,407
Total Current Assets						24,803						28,329
Long-term receivables, net						780						1,511
Investments and advances						37,655						38,688
Properties, plant and equipment, at cost						325,131						326,722
Less: Accumulated depreciation, depletion and amortization						182,748						176,228
Properties, plant and equipment, net						142,383						150,494
Deferred charges and other assets						11,227						10,532
Goodwill						4,416						4,463
Assets held for sale						1,799						3,411
Total Assets						$	223,063					$	237,428
Liabilities and Equity
Short-term debt						$	530					$	3,282
Accounts payable						9,537						14,103
Accrued liabilities						7,944						6,589
Federal and other taxes on income						788						1,554
Other taxes payable						865						1,002
Total Current Liabilities						19,664						26,530
Long-term debt						34,280						23,691
Deferred credits and other noncurrent obligations						19,267						20,445
Noncurrent deferred income taxes						10,625						13,688
Noncurrent employee benefit plans						7,189						7,866
Total Liabilities*						$	91,025					$	92,220
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 September 30, 2020 and December 31, 2019)						1,832						1,832
Capital in excess of par value						17,318						17,265
Retained earnings						163,509						174,945
Accumulated other comprehensive losses						(4,507)						(4,990)
Deferred compensation and benefit plan trust						(240)						(240)
Treasury stock, at cost (575,353,132 and 560,508,479 shares at September 30, 2020 and December 31, 2019, respectively)						(46,138)						(44,599)
Total Chevron Corporation Stockholders’ Equity						131,774						144,213
Noncontrolling interests						264						995
Total Equity						132,038						145,208
Total Liabilities and Equity						$	223,063					$	237,428
___________________________
* Refer to Note 13, “Other Contingencies and Commitments” beginning on page 16.

See accompanying notes to consolidated financial statements.

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CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF CASH FLOWS

(Unaudited)

			Nine Months Ended September 30
			2020						2019
			(Millions of dollars)
Operating Activities
Net Income (Loss)			$	(4,905)					$	9,512
Adjustments
Depreciation, depletion and amortization			15,022						12,789
Dry hole expense			848						137
Distributions more (less) than income from equity affiliates			2,249						(1,897)
Net before-tax losses (gains) on asset retirements and sales			(625)						(106)
Net foreign currency effects			190						54
Deferred income tax provision			(3,180)						986
Net decrease (increase) in operating working capital			(21)						1,126
Decrease (increase) in long-term receivables			84						426
Net decrease (increase) in other deferred charges			(145)						(144)
Cash contributions to employee pension plans			(895)						(1,204)
Other			(283)						(22)
Net Cash Provided by Operating Activities			8,339						21,657
Investing Activities
Capital expenditures			(6,855)						(9,906)
Proceeds and deposits related to asset sales and returns of investment			1,979						1,088
Net maturities of (investments in) time deposits			—						950
Net sales (purchases) of marketable securities			35						2
Net repayment (borrowing) of loans by equity affiliates			(1,434)						(970)
Net Cash Used for Investing Activities			(6,275)						(8,836)
Financing Activities
Net borrowings (repayments) of short-term obligations			(606)						1,973
Proceeds from issuances of long-term debt			12,237						—
Repayments of long-term debt and other financing obligations			(3,941)						(3,868)
Cash dividends - common stock			(7,186)						(6,731)
Distributions to noncontrolling interests			(10)						(16)
Net sales (purchases) of treasury shares			(1,545)						(1,845)
Net Cash Provided by (Used for) Financing Activities			(1,051)						(10,487)
Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash			(133)						5
Net Change in Cash, Cash Equivalents and Restricted Cash			880						2,339
Cash, Cash Equivalents and Restricted Cash at January 1			6,911						10,481
Cash, Cash Equivalents and Restricted Cash at September 30			$	7,791					$	12,820

See accompanying notes to consolidated financial statements.

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CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF EQUITY

(Unaudited)

(Millions of dollars)									Accumulated			Treasury			Chevron Corp.			Non-
			Common			Retained			Other Comp.			Stock			Stockholders’			Controlling			Total
Three Months Ended September 30			Stock(1)			Earnings			Income (Loss)			(at cost)			Equity			Interests			Equity
Balance at June 30, 2019			$	18,776		$	183,442		$	(3,357)		$	(42,466)		$	156,395		$	1,056		$	157,451
Treasury stock transactions			51			—			—			—			51			—			51
Net income (loss)			—			2,580			—			—			2,580			—			2,580
Cash dividends			—			(2,237)			—			—			(2,237)			(8)			(2,245)
Stock dividends			—			(1)			—			—			(1)			—			(1)
Other comprehensive income			—			—			88			—			88			—			88
Purchases of treasury shares			—			—			—			(1,250)			(1,250)			—			(1,250)
Issuances of treasury shares			—			—			—			216			216			—			216
Other changes, net			—			(1)			—			—			(1)			3			2
Balance at September 30, 2019			$	18,827		$	183,783		$	(3,269)		$	(43,500)		$	155,841		$	1,051		$	156,892
Balance at June 30, 2020			$	18,889		$	166,122		$	(4,750)		$	(46,143)		$	134,118		$	268		$	134,386
Treasury stock transactions			21			—			—			—			21			—			21
Net income (loss)			—			(207)			—			—			(207)			(2)			(209)
Cash dividends			—			(2,390)			—			—			(2,390)			—			(2,390)
Stock dividends			—			(1)			—			—			(1)			—			(1)
Other comprehensive income			—			—			243			—			243			—			243
Purchases of treasury shares			—			—			—			—			—			—			—
Issuances of treasury shares			—			—			—			5			5			—			5
Other changes, net			—			(15)			—			—			(15)			(2)			(17)
Balance at September 30, 2020			$	18,910		$	163,509		$	(4,507)		$	(46,138)		$	131,774		$	264		$	132,038
Nine Months Ended September 30
Balance at December 31, 2018			$	18,704		$	180,987		$	(3,544)		$	(41,593)		$	154,554		$	1,088		$	155,642
Treasury stock transactions			123			—			—			—			123			—			123
Net income (loss)			—			9,534			—			—			9,534			(22)			9,512
Cash dividends			—			(6,731)			—			—			(6,731)			(16)			(6,747)
Stock dividends			—			(2)			—			—			(2)			—			(2)
Other comprehensive income			—			—			275			—			275			—			275
Purchases of treasury shares			—			—			—			(2,789)			(2,789)			—			(2,789)
Issuances of treasury shares			—			—			—			882			882			—			882
Other changes, net			—			(5)			—			—			(5)			1			(4)
Balance at September 30, 2019			$	18,827		$	183,783		$	(3,269)		$	(43,500)		$	155,841		$	1,051		$	156,892
Balance at December 31, 2019			$	18,857		$	174,945		$	(4,990)		$	(44,599)		$	144,213		$	995		$	145,208
Treasury stock transactions			53			—			—			—			53			—			53
Net income (loss)			—			(4,878)			—			—			(4,878)			(27)			(4,905)
Cash dividends			—			(7,186)			—			—			(7,186)			(10)			(7,196)
Stock dividends			—			(2)			—			—			(2)			—			(2)
Other comprehensive income			—			—			483			—			483			—			483
Purchases of treasury shares			—			—			—			(1,751)			(1,751)			—			(1,751)
Issuances of treasury shares			—			—			—			212			212			—			212
Other changes, net			—			630			—			—			630			(694)			(64)
Balance at September 30, 2020			$	18,910		$	163,509		$	(4,507)		$	(46,138)		$	131,774		$	264		$	132,038
(Number of Shares)			Common Stock - 2020												Common Stock - 2019
Three Months Ended September 30			Issued(2)			Treasury			Outstanding						Issued(2)			Treasury			Outstanding
Balance at June 30			2,442,676,580			(575,408,748)			1,867,267,832						2,442,676,580			(544,258,109)			1,898,418,471
Purchases			—			(2,220)			(2,220)						—			(10,302,969)			(10,302,969)
Issuances			—			57,836			57,836						—			2,756,686			2,756,686
Balance at September 30			2,442,676,580			(575,353,132)			1,867,323,448						2,442,676,580			(551,804,392)			1,890,872,188
Nine Months Ended September 30
Balance at December 31			2,442,676,580			(560,508,479)			1,882,168,101						2,442,676,580			(539,838,890)			1,902,837,690
Purchases			—			(17,503,545)			(17,503,545)						—			(23,342,737)			(23,342,737)
Issuances			—			2,658,892			2,658,892						—			11,377,235			11,377,235
Balance at September 30			2,442,676,580			(575,353,132)			1,867,323,448						2,442,676,580			(551,804,392)			1,890,872,188

_________________________________________________

(1)Beginning and ending balances for all periods include capital in excess of par, common stock issued at par for $1,832, and $(240) associated with Chevron’s Benefit Plan Trust. Changes reflect capital in excess of par.

(2)Beginning and ending total issued share balances include 14,168,000 shares associated with Chevron’s Benefit Plan Trust for all periods.

See accompanying notes to consolidated financial statements.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Note 1. General

Basis of Presentation The accompanying consolidated financial statements of Chevron Corporation and its subsidiaries (together, Chevron or the company) have not been audited by an independent registered public accounting firm. In the opinion of the company’s management, the interim data includes all adjustments necessary for a fair statement of the results for the interim periods. These adjustments were of a normal recurring nature. The results for the three- and nine-month periods ended September 30, 2020, are not necessarily indicative of future financial results. The term “earnings” is defined as net income attributable to Chevron.

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 2019 Annual Report on Form 10-K.

Impact of the Coronavirus Disease 2019 (COVID-19) Pandemic The outbreak of COVID-19 and decreases in commodity prices resulting from oversupply, government-imposed travel restrictions and other constraints on economic activity have caused a significant decrease in the demand for our products and has created disruptions and volatility in the global marketplace beginning late in the first quarter 2020, which negatively affected our results of operations and cash flows. These conditions persisted throughout the third quarter and continue to negatively affect our results of operations and cash flows. While demand and commodity prices have shown signs of recovery, they are not back to pre-pandemic levels, and financial results are likely to continue to be challenged in future quarters. Due to the changing environment, there continues to be uncertainty and unpredictability around the extent to which the COVID-19 pandemic will impact our results, which could be material.

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 nine months ended September 30, 2020 and 2019 are reflected in the table below.

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

(Millions of dollars)

						Currency Translation Adjustment						Unrealized Holding Gains (Losses) on Securities						Derivatives						Defined Benefit Plans						Total
Balance at December 31, 2018						$	(124)					$	(10)					$	(2)					$	(3,408)					$	(3,544)
Components of Other Comprehensive Income (Loss):
Before Reclassifications						(32)						2						2						1						(27)
Reclassifications						—						—						—						302						302
Net Other Comprehensive Income (Loss)						(32)						2						2						303						275
Balance at September 30, 2019						$	(156)					$	(8)					$	—					$	(3,105)					$	(3,269)
Balance at December 31, 2019						$	(142)					$	(8)					$	—					$	(4,840)					$	(4,990)
Components of Other Comprehensive Income (Loss):
Before Reclassifications						5						(5)						—						9						9
Reclassifications(2)						—						—						—						474						474
Net Other Comprehensive Income (Loss)						5						(5)						—						483						483
Balance at September 30, 2020						$	(137)					$	(13)					$	—					$	(4,357)					$	(4,507)

_______________________________

(1)All amounts are net of tax.

(2)Refer to Note 9, Employee Benefits for reclassified components totaling $615 million that are included in employee benefit costs for the nine months ended September 30, 2020. Related income taxes for the same period, totaling $141 million, are reflected in “Income Tax Expense” on the Consolidated Statement of Income. All other reclassified amounts were insignificant.

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Note 3. Information Relating to the Consolidated Statement of Cash Flows

			Nine Months Ended September 30
			2020						2019
			(Millions of dollars)
Distributions more (less) than income from equity affiliates includes the following:
Distributions from equity affiliates			$	1,209					$	1,533
(Income) loss from equity affiliates			1,040						(3,430)
Distributions more (less) than income from equity affiliates			$	2,249					$	(1,897)
Net decrease (increase) in operating working capital was composed of the following:
Decrease (increase) in accounts and notes receivable			$	3,601					$	2,254
Decrease (increase) in inventories			201						(20)
Decrease (increase) in prepaid expenses and other current assets			632						(286)
Increase (decrease) in accounts payable and accrued liabilities			(3,609)						(981)
Increase (decrease) in income and other taxes payable			(846)						159
Net decrease (increase) in operating working capital			$	(21)					$	1,126
Net cash provided by operating activities includes the following cash payments:
Interest on debt (net of capitalized interest)			$	384					$	579
Income taxes			2,527						3,516
Proceeds and deposits related to asset sales and returns of investment consisted of the following gross amounts:
Proceeds and deposits related to asset sales			$	1,912					$	1,021
Returns of investment from equity affiliates			67						67
Proceeds and deposits related to asset sales and returns of investment			$	1,979					$	1,088
Net maturities of (investments in) time deposits consisted of the following gross amounts:
Investments in time deposits			$	—					$	—
Maturities of time deposits			—						950
Net maturities of (investments in) time deposits			$	—					$	950
Net sales (purchases) of marketable securities consisted of the following gross amounts:
Marketable securities purchased			$	(2)					$	(1)
Marketable securities sold			37						3
Net sales (purchases) of marketable securities			$	35					$	2
Net repayment (borrowing) of loans by equity affiliates consisted of the following gross amounts:
Borrowing of loans by equity affiliates			$	(3,925)					$	(1,050)
Repayment of loans by equity affiliates			2,491						80
Net repayment (borrowing) of loans by equity affiliates			$	(1,434)					$	(970)
Net borrowings (repayments) of short-term obligations consisted of the following gross and net amounts:
Proceeds from issuances of short-term obligations			$	8,863					$	1,821
Repayments of short-term obligations			(7,479)						(570)
Net borrowings (repayments) of short-term obligations with three months or less maturity			(1,990)						722
Net borrowings (repayments) of short-term obligations			$	(606)					$	1,973
Net sales (purchases) of treasury shares consists of the following gross and net amounts:
Shares issued for share-based compensation plans			$	206					$	944
Shares purchased under share repurchase and deferred compensation plans			(1,751)						(2,789)
Net sales (purchases) of treasury shares			$	(1,545)					$	(1,845)

The Consolidated Statement of Cash Flows excludes changes to the Consolidated Balance Sheet that did not affect cash.

The “Other” line in the Operating Activities section includes changes in postretirement benefits obligations and other long-term liabilities.

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The company paid dividends of $1.29 per share of common stock in third quarter 2020 and $3.87 per share in the first nine months of 2020. This compares to dividends of $1.19 and $3.57 per share paid in the corresponding year-ago periods.

The major components of “Capital expenditures” and the reconciliation of this amount to the reported capital and exploratory expenditures, including equity affiliates, are presented in the following table:

			Nine Months Ended September 30
			2020						2019
			(Millions of dollars)
Additions to properties, plant and equipment			$	6,576					$	9,713
Additions to investments			86						69
Current-year dry hole expenditures			226						111
Payments for other assets and liabilities, net			(33)						13
Capital expenditures			6,855						9,906
Expensed exploration expenditures			322						361
Assets acquired through finance lease obligations and other financing obligations			49						146
Payments for other assets and liabilities, net			33						(13)
Capital and exploratory expenditures, excluding equity affiliates			7,259						10,400
Company’s share of expenditures by equity affiliates			3,063						4,578
Capital and exploratory expenditures, including equity affiliates			$	10,322					$	14,978

The table below quantifies the beginning and ending balances of restricted cash and restricted cash equivalents in the Consolidated Balance Sheet:

			At September 30												At December 31
			2020						2019						2019						2018
			(Millions of dollars)
Cash and Cash Equivalents			$	6,866					$	11,697					$	5,686					$	9,342
Restricted cash included in “Prepaid expenses and other current assets”			169						370						452						341
Restricted cash included in “Deferred charges and other assets”			756						753						773						798
Total Cash, Cash Equivalents and Restricted Cash			$	7,791					$	12,820					$	6,911					$	10,481

Additional information related to “Restricted Cash” is included on page 19 in Note 14 under the heading “Restricted Cash.”

Note 4. New Accounting Standards

Financial Instruments - Credit Losses (Topic 326) Effective January 1, 2020, Chevron adopted Accounting Standards Update (ASU) 2016-13 and its related amendments. For additional information on the company’s expected credit losses, refer to Note 17 on page 21.

Note 5. 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:

			Nine Months Ended September 30
			2020						2019
			(Millions of dollars)
Sales and other operating revenues			$	6,757					$	11,991
Costs and other deductions			4,655						5,971
Net income attributable to TCO			$	1,483					$	4,230

Note 6. 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 on the next page:

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			Nine Months Ended September 30
			2020						2019
			(Millions of dollars)
Sales and other operating revenues			$	6,093					$	7,209
Costs and other deductions			5,179						5,992
Net income attributable to CPChem			$	877					$	1,464

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.

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

			Nine Months Ended September 30
			2020						2019
			(Millions of dollars)
Sales and other operating revenues			$	50,360					$	82,073
Costs and other deductions			54,221						79,794
Net income (loss) attributable to CUSA			$	(2,203)					$	2,149

			At September 30, 2020						At December 31, 2019
			(Millions of dollars)
Current assets			$	9,523					$	13,059
Other assets			49,582						50,796
Current liabilities			12,062						18,291
Other liabilities			14,415						12,565
Total CUSA net equity			$	32,628					$	32,999
Memo: Total debt			$	7,132					$	3,222

Note 8. 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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Segment Earnings The company evaluates the performance of its operating segments on an after-tax basis, without considering the effects of debt financing interest expense or investment interest income, both of which are managed by the company on a worldwide basis. Corporate administrative costs and assets are not allocated to the operating segments. However, operating segments are billed for the direct use of corporate services. Nonbillable costs remain at the corporate level in “All Other.” Earnings by major operating area for the three- and nine-month periods ended September 30, 2020 and 2019, are presented in the following table:

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
Segment Earnings			(Millions of dollars)												(Millions of dollars)
Upstream
United States			$	116					$	727					$	(1,709)					$	2,371
International			119						1,977						(1,225)						6,939
Total Upstream			235						2,704						(2,934)						9,310
Downstream
United States			141						389						(397)						1,071
International			151						439						782						738
Total Downstream			292						828						385						1,809
Total Segment Earnings			527						3,532						(2,549)						11,119
All Other
Interest expense			(153)						(187)						(471)						(591)
Interest income			7						48						43						142
Other			(588)						(813)						(1,901)						(1,136)
Net Income Attributable to Chevron Corporation			$	(207)					$	2,580					$	(4,878)					$	9,534

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 September 30, 2020, and December 31, 2019, are as follows: 

			At September 30, 2020						At December 31, 2019
Segment Assets			(Millions of dollars)
Upstream
United States			$	33,574					$	35,926
International			135,540						145,648
Goodwill			4,416						4,463
Total Upstream			173,530						186,037
Downstream
United States			23,335						25,197
International			16,056						16,955
Total Downstream			39,391						42,152
Total Segment Assets			212,921						228,189
All Other
United States			4,515						3,475
International			5,627						5,764
Total All Other			10,142						9,239
Total Assets — United States			61,424						64,598
Total Assets — International			157,223						168,367
Goodwill			4,416						4,463
Total Assets			$	223,063					$	237,428

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Segment Sales and Other Operating Revenues Segment sales and other operating revenues, including internal transfers, for the three- and nine-month periods ended September 30, 2020 and 2019, 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 September 30												Nine Months Ended September 30
			2020						2019						2020						2019
Sales and Other Operating Revenues			(Millions of dollars)												(Millions of dollars)
Upstream
United States			$	3,367					$	5,602					$	10,377					$	17,411
International			5,911						8,607						19,478						26,953
Subtotal			9,278						14,209						29,855						44,364
Intersegment Elimination — United States			(1,916)						(3,686)						(6,148)						(11,070)
Intersegment Elimination — International			(1,661)						(3,015)						(5,223)						(9,411)
Total Upstream			5,701						7,508						18,484						23,883
Downstream
United States			8,147						14,224						24,568						41,467
International			10,649						14,230						29,341						43,438
Subtotal			18,796						28,454						53,909						84,905
Intersegment Elimination — United States			(307)						(1,017)						(1,899)						(3,006)
Intersegment Elimination — International			(230)						(227)						(1,001)						(678)
Total Downstream			18,259						27,210						51,009						81,221
All Other
United States			208						270						645						763
International			3						5						11						12
Subtotal			211						275						656						775
Intersegment Elimination — United States			(171)						(209)						(510)						(576)
Intersegment Elimination — International			(3)						(5)						(11)						(12)
Total All Other			37						61						135						187
Sales and Other Operating Revenues
United States			11,722						20,096						35,590						59,641
International			16,563						22,842						48,830						70,403
Subtotal			28,285						42,938						84,420						130,044
Intersegment Elimination — United States			(2,394)						(4,912)						(8,557)						(14,652)
Intersegment Elimination — International			(1,894)						(3,247)						(6,235)						(10,101)
Total Sales and Other Operating Revenues			$	23,997					$	34,779					$	69,628					$	105,291

Note 9. Employee Benefits

Chevron has defined benefit pension plans for many employees. The company typically prefunds defined benefit plans as required by local regulations or in certain situations where prefunding provides economic advantages. In the United States, all qualified plans are subject to the Employee Retirement Income Security Act minimum funding standard. The company does not typically fund U.S. nonqualified pension plans that are not subject to funding requirements under laws and regulations because contributions to these pension plans may be less economic and investment returns may be less attractive than the company’s other investment alternatives.

The company also sponsors other postretirement employee benefit (OPEB) plans that provide medical and dental benefits, as well as life insurance for some active and qualifying retired employees. The plans are

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unfunded, and the company and the retirees share the costs. For the company’s main U.S. medical plan, the increase to the pre-Medicare company contribution for retiree medical coverage is limited to no more than 4 percent each year. Certain life insurance benefits are paid by the company.

The components of net periodic benefit costs for 2020 and 2019 are as follows:

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)									(Millions of dollars)
Pension Benefits
United States
Service cost			$	124					$	101					$	373					$	304
Interest cost			89						100						265						298
Expected return on plan assets			(163)						(141)						(488)						(423)
Amortization of prior service costs (credits)			—						—						1						1
Amortization of actuarial losses (gains)			96						60						288						179
Settlement losses			184						87						304						207
Total United States			330						207						743						566
International
Service cost			33						34						97						105
Interest cost			44						49						131						153
Expected return on plan assets			(52)						(56)						(155)						(171)
Amortization of prior service costs (credits)			2						3						7						9
Amortization of actuarial losses (gains)			12						4						33						15
Settlement losses			—						—						—						1
Total International			39						34						113						112
Net Periodic Pension Benefit Costs			$	369					$	241					$	856					$	678
Other Benefits*
Service cost			$	9					$	9					$	28					$	27
Interest cost			18						24						53						72
Amortization of prior service costs (credits)			(7)						(7)						(21)						(21)
Amortization of actuarial losses (gains)			1						(1)						3						(2)
Net Periodic Other Benefit Costs			$	21					$	25					$	63					$	76

_ ___________________________________

* 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 September 30, 2020, a total of $895 million was contributed to employee pension plans (including $726 million to the U.S. plans). 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 nine months of 2020, the company contributed $120 million to its OPEB plans. The company anticipates contributing approximately $54 million during the remainder of 2020.

Note 10. Assets Held For Sale

At September 30, 2020, the company classified $1.80 billion of net properties, plant and equipment as “Assets held for sale” on the Consolidated Balance Sheet. These assets are associated with upstream operations that are anticipated to be sold in the next 12 months. The revenues and earnings contributions of these assets in 2019 and the first nine months of 2020 were not material.

Note 11. Income Taxes

The income tax expense decreased between quarterly periods from $1.47 billion in 2019 to $165 million in 2020. The company's income before income tax expense decreased $4.09 billion from $4.05 billion in 2019 to a loss of $44 million in 2020, primarily due to the decrease in crude prices and production. The company’s effective tax rate changed between quarterly periods from 36 percent in 2019 to negative 375 percent in 2020.

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The change in the effective tax rate is primarily due to the one-time tax charge in an international location and the 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 income tax expense decreased between the nine-month periods from a charge of $4.43 billion in 2019 to a benefit of $1.59 billion in 2020. This decrease is a direct result of the company’s income before income tax expense decreasing $20.44 billion, from $13.94 billion in 2019 to a loss of $6.50 billion in 2020. The decrease in income is primarily due to the reduction in prices and production, impairments and other corporate charges. The company’s effective tax rate changed between nine-month periods from 32 percent in 2019 to 24 percent in 2020. The reduction in the effective tax rate is primarily due to the 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 and is also due to the impact of tax benefits for releasing the reserve on an uncertain tax position, valuation allowance release and a tax rate change.

Tax positions for Chevron and its subsidiaries and affiliates are subject to income tax audits by many tax jurisdictions throughout the world. For the company’s major tax jurisdictions, examinations of tax returns for certain prior tax years had not been completed as of September 30, 2020. For these jurisdictions, the latest years for which income tax examinations had been finalized were as follows: United States — 2013, Nigeria — 2007, Australia — 2009 and Kazakhstan — 2012.

The company engages in ongoing discussions with tax authorities regarding the resolution of tax matters in the various jurisdictions. Both the outcomes for these tax matters and the timing of resolution and/or closure of the tax audits are highly uncertain. However, it is reasonably possible that developments regarding tax matters in certain tax jurisdictions may result in significant increases or decreases in the company’s total unrecognized tax benefits within the next 12 months. Given the number of years that still remain subject to examination and the number of matters being examined in the various tax jurisdictions, the company is unable to estimate the range of possible adjustments to the balance of unrecognized tax benefits.

Note 12. 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 six 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

Texaco Petroleum Company (Texpet), a subsidiary of Texaco Inc., was a minority member of an oil production consortium in Ecuador from 1967 until 1992, with state-owned Petroecuador as the majority partner. Upon termination of the consortium, and following a third-party environmental audit, Ecuador and the consortium parties entered into a settlement agreement specifying Texpet’s environmental remediation obligations. After Texpet completed a three-year remediation program, Ecuador certified that the remediation was properly conducted and released Texpet and its related corporate entities from environmental liability.

In May 2003, plaintiffs alleging environmental harm from the consortium’s activities filed a civil lawsuit against Chevron in the Superior Court for the province of Nueva Loja in Lago Agrio, Ecuador. Chevron defended itself on multiple grounds, including that the lawsuit was barred by the settlement and releases from Ecuador and that the evidence confirmed Texpet’s remediation was properly conducted and any remaining environmental impacts were due to Petroecuador’s failure to remediate its own majority share of the concession area and to Petroecuador’s conduct as sole owner of expanded operations in the area since 1992. In February 2011, the Ecuadorian provincial court entered a judgment against Chevron for approximately $9.5 billion plus additional punitive damages. In January 2012, an appellate panel affirmed the judgment and

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ordered that Chevron pay an additional 0.10% in attorneys’ fees. In November 2013, Ecuador’s National Court of Justice ratified the judgment but nullified the punitive damage assessment, resulting in a judgment of $9.5 billion. Ecuador’s highest Constitutional Court rejected Chevron’s final appeal in July 2018.

In February 2011, Chevron filed a civil lawsuit against the Lago Agrio plaintiffs and several of their lawyers and supporters in the U.S. District Court for the Southern District of New York, asserting violations of the Racketeer Influenced and Corrupt Organizations (RICO) Act and state law. After a trial, the New York court ruled in favor of Chevron, finding that the Ecuadorian judgment had been procured through fraud, bribery, and corruption, and prohibiting the RICO defendants from seeking to enforce the Ecuadorian judgment in the United States or profiting from their illegal acts. The U.S. Court of Appeals for the Second Circuit unanimously affirmed, and the U.S. Supreme Court denied certiorari in June 2017, rendering final the New York judgment in favor of Chevron.

The Lago Agrio plaintiffs’ lawyers sought to have the Ecuadorian judgment recognized and enforced in Canada, Brazil, and Argentina. All of those recognition and enforcement actions have been finally resolved in Chevron’s favor. In Canada, following dismissal of Chevron Canada Limited from the action, the Ontario Superior Court ordered a final dismissal of the action against Chevron Corporation in July 2019 by consent of the parties. In Brazil and Argentina, after public prosecutors in each country recommended rejection of the plaintiffs’ action on grounds including that the Ecuadorian judgment was procured through fraud and corruption, Brazil’s Superior Court of Justice dismissed and the Supreme Court of Argentina affirmed dismissal by the lower court of the actions on jurisdictional grounds in rulings that became final in June 2018 and July 2020, respectively.

Chevron and Texpet filed an arbitration claim against Ecuador in September 2009 before an arbitral tribunal administered by the Permanent Court of Arbitration in The Hague, under the United States-Ecuador Bilateral Investment Treaty. In September 2013, the Tribunal issued a first partial award holding that, although the settlement and release agreements between Ecuador and Texpet did not preclude individual claims for personal harm, they did release Texpet and Chevron from public environmental claims. In August 2018, the Tribunal issued a second partial award holding that the Ecuadorian judgment was based on public claims that Ecuador had settled and released and that it was procured through fraud, bribery, and corruption. According to the Tribunal, the Ecuadorian judgment “violates international public policy” and “should not be recognized or enforced by the courts of other States.” The Tribunal ordered Ecuador to take immediate steps to remove the status of enforceability from the Ecuadorian judgment and to compensate Chevron for any injuries resulting from the judgment. The third and final phase of the arbitration, to determine the amount of compensation Ecuador owes to Chevron, is ongoing. The District Court of The Hague denied a request by Ecuador to set aside the Arbitration Tribunal’s first partial award, and the Appeals Court and Supreme Court of the Netherlands upheld that denial. On September 16, 2020, the District Court of The Hague denied Ecuador’s request to set aside the Tribunal’s second partial award, holding that the award was well reasoned and complied with applicable law and public policy, and properly sought to “remov[e] the consequences of a fraudulent judgment that was rendered by a corrupt judge.” The District Court further recorded that it now is “common ground” between Ecuador and Chevron that the Ecuadorian judgment is fraudulent.

Management’s Assessment The ultimate outcome of the foregoing matters, including any financial effect on Chevron, remains uncertain. Chevron continues to believe that the Ecuadorian judgment is illegitimate and unenforceable and that it does not provide any basis upon which an estimate of a reasonably possible loss or range of loss can be made.

Note 13. 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 beginning on page 14 for a discussion of the periods for which tax returns have been audited for the company’s major tax jurisdictions.

Settlement of open tax years, as well as other tax issues in countries where the company conducts its businesses, are not expected to have a material effect on the consolidated financial position or liquidity of the

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company and, in the opinion of management, adequate provision has been made for income taxes for all years under examination or subject to future examination.

Guarantees The company and its subsidiaries have certain contingent liabilities with respect to guarantees, direct or indirect, of debt of affiliated companies or third parties. Under the terms of the guarantee arrangements, the company would generally be required to perform should the affiliated company or third party fail to fulfill its obligations under the arrangements. In some cases, the guarantee arrangements may have recourse provisions that would enable the company to recover any payments made under the terms of the guarantees from assets provided as collateral.

Indemnifications In the acquisition of Unocal, the company assumed certain indemnities relating to contingent environmental liabilities associated with assets that were sold in 1997. The acquirer of those assets shared in certain environmental remediation costs up to a maximum obligation of $200 million, which had been reached at December 31, 2009. Under the indemnification agreement, after reaching the $200 million obligation, Chevron is solely responsible until April 2022, when the indemnification expires. The environmental conditions or events that are subject to these indemnities must have arisen prior to the sale of the assets in 1997.

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 may relate to suppliers’ financing arrangements. The agreements typically provide goods and services, such as pipeline and storage capacity, 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 factors such as the unknown magnitude of possible contamination, the unknown timing and extent of the corrective actions that may be required, the determination of the company’s liability in proportion to other responsible parties, and the extent to which such costs are recoverable from third parties.

Although the company has provided for known environmental obligations that are probable and reasonably estimable, the amount of additional future costs may be material to results of operations in the period in which they are recognized. The company does not expect these costs will have a material effect on its consolidated financial position or liquidity. Also, the company does not believe its obligations to make such expenditures have had, or will have, any significant impact on the company’s competitive position relative to other U.S. or international petroleum or chemical companies.

Other Contingencies Governmental and other entities in California and other jurisdictions have filed legal proceedings against fossil fuel producing companies, including Chevron, purporting to seek legal and equitable relief to address alleged impacts of climate change. Further such proceedings are likely to be filed by other parties. The unprecedented legal theories set forth in these proceedings entail the possibility of damages liability and injunctions, including without limitation injunctions against the production of all fossil fuels, that, while we believe remote, could have a material adverse effect on the Company’s results of operations and financial condition. Management believes that these proceedings are legally and factually meritless and detract from constructive efforts to address the important policy issues presented by climate change, and will vigorously defend against such proceedings.

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Seven coastal parishes and the State of Louisiana have filed 43 separate lawsuits in Louisiana against numerous oil and gas companies seeking damages for coastal erosion in or near oil fields located within Louisiana’s coastal zone under Louisiana’s State and Local Coastal Resources Management Act (SLCRMA). Chevron entities are defendants in 39 of these cases. The lawsuits allege that the defendants’ historical operations were conducted without necessary permits or failed to comply with permits obtained and seek damages and other relief, including the costs of restoring coastal wetlands allegedly impacted by oil field operations. Plaintiffs’ SLCRMA theories are unprecedented; thus, there remains significant uncertainty about the scope of the claims and alleged damages and any potential effects on the company’s results of operations and financial condition. Management believes that the claims lack legal and factual merit and will continue to vigorously defend against such proceedings.

Chevron receives claims from and submits claims to customers; trading partners; joint venture partners; U.S. federal, state and local regulatory bodies; governments; contractors; insurers; suppliers; and individuals. The amounts of these claims, individually and in the aggregate, may be significant and take lengthy periods to resolve, and may result in gains or losses in future periods.

The company and its affiliates also continue to review and analyze their operations and may close, decommission, 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 14. Fair Value Measurements

The three levels of the fair value hierarchy of inputs the company uses to measure the fair value of an asset or liability are described as follows:

Level 1: Quoted prices (unadjusted) in active markets for identical assets and liabilities. For the company, Level 1 inputs include exchange-traded futures contracts for which the parties are willing to transact at the exchange-quoted price and marketable securities that are actively traded.

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

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

The fair value hierarchy for assets and liabilities measured at fair value on a recurring basis at September 30, 2020, and December 31, 2019, is as follows:

Assets and Liabilities Measured at Fair Value on a Recurring Basis

(Millions of dollars)

			At September 30, 2020																								At December 31, 2019
			Total						Level 1						Level 2						Level 3						Total						Level 1						Level 2						Level 3
Marketable Securities			$	28					$	28					$	—					$	—					$	63					$	63					$	—					$	—
Derivatives			104						55						49						—						11						1						10						—
Total Assets at Fair Value			$	132					$	83					$	49					$	—					$	74					$	64					$	10					$	—
Derivatives			8						5						3						—						74						26						48						—
Total Liabilities at Fair Value			$	8					$	5					$	3					$	—					$	74					$	26					$	48					$	—

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 September 30, 2020.

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

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futures, swaps and options contracts traded in active markets such as the New York Mercantile Exchange. Derivatives classified as Level 2 include swaps, options and forward contracts principally with financial institutions and other oil and gas companies, the fair values of which are obtained from third-party broker quotes, industry pricing services and exchanges. The company obtains multiple sources of pricing information for the Level 2 instruments. Since this pricing information is generated from observable market data, it has historically been very consistent. The company does not materially adjust this information.

Assets carried at fair value at September 30, 2020, and December 31, 2019, are as follows:

Cash and Cash Equivalents The company holds cash equivalents in U.S. and non-U.S. portfolios. The instruments classified as cash equivalents are primarily bank time deposits with maturities of 90 days or less, and money market funds. “Cash and cash equivalents” had carrying/fair values of $6.9 billion and $5.7 billion at September 30, 2020, and December 31, 2019, 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 September 30, 2020.

Restricted Cash had a carrying/fair value of $925 million and $1.2 billion at September 30, 2020 and December 31, 2019, respectively. At September 30, 2020, restricted cash is classified as Level 1 and includes restricted funds related to certain upstream decommissioning activities, other corporate and tax items, 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 debt and finance lease obligations, of $24.2 billion and $13.7 billion at September 30, 2020, and December 31, 2019, respectively. The fair value of long-term debt for the company was $25.7 billion and $14.3 billion at September 30, 2020 and December 31, 2019, respectively. Long-term debt primarily includes corporate issued bonds, classified as Level 1 and are $24.6 billion for the period. The fair value of other long-term debt classified as Level 2 is $1.1 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 September 30, 2020, and December 31, 2019, were not material.

The fair value hierarchy for assets and liabilities measured at fair value on a nonrecurring basis at September 30, 2020, is as follows:

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

(Millions of dollars)

			At September 30, 2020
																											Before-Tax Loss
																											Three Months Ended						Nine Months Ended
			Total						Level 1						Level 2						Level 3
Properties, plant and equipment, net (held and used)			$	—					$	—					$	—					$	—					$	—					$	2,551
Properties, plant and equipment, net (held for sale)			22						—						22						—						17						183
Investments and advances			—						—						—						—						—						2,550
Total Assets at Fair Value			$	22					$	—					$	22					$	—					$	17					$	5,284

Properties, plant and equipment Through September 2020, the company reported impairments for certain upstream properties primarily due to downward revisions to its oil and gas price outlook. The impact of these impairments is included in “Depreciation, depletion, and amortization” on the Consolidated Statement of Income. The company did not have any individually material impairments of long-lived assets measured at fair value on a nonrecurring basis to report in third quarter 2020.

Investments and advances Through September 2020, the company fully impaired its investments in the Petropiar and Petroboscan affiliates in Venezuela. The impact of these impairments is included in “Income (loss) from equity affiliates” on the Consolidated Statement of Income. The company did not have any

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material impairments of investments and advances measured at fair value on a nonrecurring basis to report in third quarter 2020.

Note 15. Financial and Derivative Instruments

The company’s derivative instruments principally include crude oil, natural gas and refined product futures, swaps, options, and forward contracts. None of the company’s derivative instruments are designated as hedging instruments, although certain of the company’s affiliates make such a designation. The company’s derivatives are not material to the company’s consolidated financial position, results of operations or liquidity. The company believes it has no material market or credit risks to its operations, financial position or liquidity as a result of its commodities and other derivatives activities.

The company uses derivative commodity instruments traded on the New York Mercantile Exchange and on electronic platforms of the Inter-Continental Exchange and Chicago Mercantile Exchange. In addition, the company enters into swap contracts and option contracts principally with major financial institutions and other oil and gas companies in the “over-the-counter” markets, which are governed by International Swaps and Derivatives Association agreements and other master netting arrangements.

Derivative instruments measured at fair value at September 30, 2020, and December 31, 2019, 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 September 30, 2020						At December 31, 2019
Commodity						Accounts and notes receivable, net						$	90					$	11
Commodity						Long-term receivables, net						14						—
Total Assets at Fair Value												$	104					$	11
Commodity						Accounts payable						$	3					$	74
Commodity						Deferred credits and other noncurrent obligations						5						—
Total Liabilities at Fair Value												$	8					$	74

Consolidated Statement of Income: The Effect of Derivatives Not Designated as Hedging Instruments (Millions of dollars)
Type of												Gain / (Loss) Three Months Ended September 30												Gain / (Loss) Nine Months Ended September 30
Contract						Statement of Income Classification						2020						2019						2020						2019
Commodity						Sales and other operating revenues						$	38					$	55					$	283					$	(189)
Commodity						Purchased crude oil and products						(7)						(7)						(31)						(16)
Commodity						Other income						6						—						3						(3)
												$	37					$	48					$	255					$	(208)

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The table below represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at September 30, 2020, and December 31, 2019.

Consolidated Balance Sheet: The Effect of Netting Derivative Assets and Liabilities (Millions of dollars)
						Gross Amount Recognized						Gross Amounts Offset						Net Amounts Presented						Gross Amounts Not Offset						Net Amount
At September 30, 2020
Derivative Assets						$	1,044					$	940					$	104					$	—					$	104
Derivative Liabilities						$	948					$	940					$	8					$	—					$	8
At December 31, 2019
Derivative Assets						$	656					$	645					$	11					$	—					$	11
Derivative Liabilities						$	719					$	645					$	74					$	—					$	74

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 16. Revenue

“Sales and other operating revenue” on the Consolidated Statement of Income primarily arise from contracts with customers. Related receivables are included in “Accounts and notes receivable, net” on the Consolidated Balance Sheet, net of the current expected credit losses. The net balance of these receivables was $6.3 billion and $9.2 billion at September 30, 2020, and December 31, 2019, respectively. Other items included in “Accounts and notes receivable, net” represent amounts due from partners for their share of joint venture operating and project costs and amounts due from others, primarily related to derivatives, leases, buy/sell arrangements and product exchanges, which are accounted for outside the scope of ASC 606.

Note 17. Financial Instruments - Credit Losses

Chevron adopted Accounting Standards Update (ASU) 2016-13, Financial Instruments - Credit Losses, and its related amendments at the effective date of January 1, 2020. The standard replaces the “incurred loss model” and requires an estimate of expected credit losses, measured over the contractual life of a financial instrument, that considers forecast of future economic conditions in addition to information about past events and current conditions. The cumulative-effect adjustment to the opening retained earnings at January 1, 2020 was a reduction of $25 million, representing a decrease to the net accounts and notes receivable balances shown on the company’s consolidated balance sheet on page 5. Chevron’s expected credit loss allowance balance was $666 million as of September 30, 2020 and $849 million as of December 31, 2019, with a majority of the allowance relating to non-trade receivable balances. A reduction in the allowance for non-trade receivables of $550 million was recorded in the second quarter as an agreement was reached with a government joint venture partner that resulted in the write-off of the associated receivable balances. Additionally, new allowances of $265 million were recorded in the second and third quarters associated with other than trade receivables.

The majority of the company’s receivable balance is concentrated in trade receivables, with a balance of $8.1 billion as of September 30, 2020, which reflects the company’s diversified sources of revenues and is dispersed across the company’s broad worldwide customer base. As a result, the company believes the concentration of credit risk is limited. The company routinely assesses the financial strength of its customers. When the financial strength of a customer is not considered sufficient, alternative risk mitigation measures may be deployed, including requiring pre-payments, letters of credit or other acceptable forms of collateral. Once credit is extended and a receivable balance exists, the company applies a quantitative calculation to current trade receivable balances that reflects credit risk predictive analysis, including probability of default and loss given default, which takes into consideration current and forward-looking market data as well as the company’s historical loss data. This statistical approach becomes the basis of the company’s expected credit loss allowance for current trade receivables with payment terms that are typically short-term in nature, with

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most due in less than 90 days. The company continues to monitor credit risk in response to the COVID-19 pandemic and the significant reduction in crude prices resulting from decreased demand associated with government-mandated travel restrictions.

Chevron's non-trade receivable balance was $3.1 billion as of September 30, 2020, which includes receivables from certain governments in their capacity as joint venture partners. Joint venture partner balances that are paid as per contract terms or not yet due are subject to the statistical analysis described above while past due balances are subject to additional qualitative management quarterly review. This management review includes review of reasonable and supportable repayment forecasts. Non-trade receivables also include employee and tax receivables that are deemed immaterial and low risk.

Equity affiliate loans are also considered non-trade and during the second quarter 2020 review, a $560 million allowance was recognized within “Investments and advances” on the Consolidated Balance Sheet.

Note 18. Accounting for Suspended Exploratory Wells

The capitalized cost of suspended wells at September 30, 2020, was $2.5 billion, a net decrease of $574 million from year-end 2019. The decrease was primarily due to well write-offs recorded in second quarter 2020. During the nine months ended September 30, 2020, $496 million of exploratory well costs previously capitalized for greater than one year at December 31, 2019, were charged to expense.

Note 19. Long-Term Debt

The company issued $8 billion and an additional $4 billion in aggregate principal amount of floating and fixed rate notes in May 2020 and August 2020, respectively, as detailed in the table below. In the first nine months of 2020, the company repaid $3.9 billion of bonds at maturity.

May 2020 issuance:						Principal (Millions of dollars)
Floating rate notes due 2023						$	300
1.141% notes due 2023						1,200
1.554% notes due 2025						2,500
1.995% notes due 2027						1,000
2.236% notes due 2030						1,500
2.978% notes due 2040						500
3.078% notes due 2050						1,000
Total Long-Term Debt Issued in May 2020						$	8,000
August 2020 issuance:						Principal (Millions of dollars)
Floating rate notes due 2022						$	350
0.333% notes due 2022						400
Floating rate notes due 2023						500
0.426% notes due 2023						500
0.687% notes due 2025						750
1.018% notes due 2027						750
2.343% notes due 2050						750
Total Long-Term Debt Issued in August 2020						$	4,000

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Note 20. Restructuring and Reorganization Costs

In third quarter 2020, the company recorded adjustments and additional charges for employee reduction programs related to enterprise-wide restructuring, which are expected to be substantially completed by the end of 2021. The following table summarizes the accrued severance liability, which is classified as current on the Consolidated Balance Sheet.

			Amounts Before Tax
			(Millions of dollars)
Balance at January 1, 2020			$	7
Accruals/Adjustments			1,018
Payments			(133)
Balance at September 30, 2020			$	892

Note 21. Acquisition of Noble Energy, Inc.

On October 5, 2020, the company acquired Noble Energy, Inc. (Noble), an independent oil and gas exploration and production company. Noble’s principal upstream operations are in North America, the Eastern Mediterranean and West Africa. Noble’s operations also include an integrated midstream business in North America.

The aggregate purchase price of Noble was $4.1 billion, with approximately 58 million shares of Chevron common stock issued as consideration in the transaction. As part of the transaction, the company assumed debt with a book value of $7.7 billion. The shares represented approximately 3 percent of shares of Chevron common stock outstanding immediately after the transaction closed on October 5, 2020.

The acquisition will be accounted for as a business combination under ASC 805, which requires assets acquired and liabilities assumed to be measured at their acquisition date fair value. Provisional fair value measurement will be made in the fourth quarter 2020 for acquired assets and assumed liabilities, and adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date as information necessary to complete the analysis is obtained.

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

Third Quarter 2020 Compared with Third Quarter 2019

And Nine Months 2020 Compared with Nine Months 2019

Key Financial Results

Earnings by Business Segment
			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)												(Millions of dollars)
Upstream
United States			$	116					$	727					$	(1,709)					$	2,371
International			119						1,977						(1,225)						6,939
Total Upstream			235						2,704						(2,934)						9,310
Downstream
United States			141						389						(397)						1,071
International			151						439						782						738
Total Downstream			292						828						385						1,809
Total Segment Earnings			527						3,532						(2,549)						11,119
All Other			(734)						(952)						(2,329)						(1,585)
Net Income (Loss) Attributable to Chevron Corporation (1) (2)			$	(207)					$	2,580					$	(4,878)					$	9,534
__________________________________________
(1) Includes foreign currency effects.			$	(188)					$	74					$	(111)					$	(48)
(2) Income (loss) net of tax; also referred to as “earnings” in the discussions that follow.

Net loss attributable to Chevron Corporation for third quarter 2020 was $207 million ($(0.12) per share — diluted), compared with earnings of $2.58 billion ($1.36 per share — diluted) in the corresponding 2019 period. The net loss attributable to Chevron Corporation for the first nine months of 2020 was $4.88 billion ($(2.63) per share — diluted), compared with earnings of $9.53 billion ($5.02 per share — diluted) in the first nine months of 2019.

Upstream reported earnings of $235 million in third quarter 2020 compared with $2.70 billion in the corresponding 2019 period. The decrease was driven by lower crude oil and natural gas realizations and lower crude oil and natural gas volumes. Upstream reported a loss of $2.93 billion for the first nine months of 2020 compared with earnings of $9.31 billion a year earlier. The decrease was driven by lower crude oil and natural gas realizations, and charges for impairments and write-offs.

Downstream reported earnings of $292 million in third quarter 2020 compared with $828 million in the corresponding 2019 period. The decrease was primarily due to lower margins on refined product sales and lower sales volumes, partially offset by lower operating expenses. Earnings for the first nine months of 2020 were $385 million compared with $1.81 billion in the corresponding 2019 period. The decrease was primarily due to lower sales volumes, lower margins on refined product sales and lower equity earnings from 50 percent-owned Chevron Phillips Chemical Company LLC (CPChem).

Refer to pages 30 through 32 for additional discussion of results by business segment and “All Other” activities for third quarter and first nine months 2020 versus the same periods in 2019.

Business Environment and Outlook

Chevron Corporation* is a global energy company with substantial business activities in the following countries: Angola, Argentina, Australia, Bangladesh, Brazil, Canada, China, Colombia, Indonesia, Kazakhstan, Myanmar, Mexico, Nigeria, the Partitioned Zone between Saudi Arabia and Kuwait, the Philippines, Republic of Congo, Singapore, South Korea, Thailand, the United Kingdom, the United States, and Venezuela.

_____________________

* Incorporated in Delaware in 1926 as Standard Oil Company of California, the company adopted the name Chevron Corporation in 1984 and ChevronTexaco Corporation in 2001. In 2005, ChevronTexaco Corporation changed its name to Chevron Corporation. As used in this report, the term “Chevron” and such terms as “the company,” “the corporation,” “our,” “we,” “us” and "its" may refer to Chevron Corporation, one or more of its consolidated subsidiaries, or all of them taken as a whole, but unless stated otherwise they do not include “affiliates” of Chevron — i.e., those companies generally owned 50 percent or less. 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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Earnings of the company depend mostly on the profitability of its upstream business segment. The most significant factor affecting the results of operations for the upstream segment is the price of crude oil, which is determined in global markets outside of the company’s control. 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 stockholder value in any business environment. Periods of sustained lower prices could result in the impairment or write-off of specific assets in future periods and cause the company to adjust operating expenses, including employee reductions, and capital and exploratory expenditures, along with other measures intended to improve financial performance. Similarly, impairments or write-offs have occurred, and may occur in the future, as a result of managerial decisions not to progress certain projects in the company’s portfolio.

Response to Market Conditions and COVID-19 During the third quarter of 2020, travel restrictions and other constraints on economic activity continued in many locations around the world to limit the spread of the COVID-19 virus. Lower commodity prices negatively impacted the company’s third quarter 2020 financial and operating results. While demand and commodity prices have shown signs of recovery, they are not back to pre-pandemic levels, and financial results will likely continue to be challenged in future quarters. Due to the rapidly changing environment, there continues to be uncertainty and unpredictability around the extent to which the COVID-19 pandemic will impact our results, which could be material.

Chevron entered this crisis well positioned with a strong balance sheet, flexible capital program and low cash flow breakeven price. To protect its long-term health and value, the company is responding to these market conditions by adjusting items it can control. The company has lowered planned 2020 capital expenditures by up to 30 percent from its original budget to $14 billion and is on track to lower 2020 operating costs by $1 billion compared to 2019. The company is undertaking an enterprise-wide transformation that includes the capture of cost efficiencies. As part of this restructuring, employee reduction programs were announced. Additionally, the company suspended its share repurchase program in March 2020. Taken together, these actions are consistent with our financial priorities: to protect the dividend, to prioritize capital spend that drives long-term value and to maintain a strong balance sheet. The company expects to continue to have sufficient liquidity and access to both commercial paper and debt capital markets due to its strong balance sheet and investment grade credit ratings. Additionally, the company has access to nearly $10 billion in committed credit facilities.

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. Additional information related to the company’s effective income tax rate is included in Note 11 to the Consolidated Financial Statements.

Refer to the “Cautionary Statement Relevant to Forward-Looking Information” on page 2 of this report and to “Risk Factors” on pages 18 through 21 of the company’s 2019 Annual Report on Form 10-K and on pages 41 to 42 of this report 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. Asset dispositions and restructurings may result in significant gains or losses in future periods. The company’s asset sale program for 2018 through 2020 is targeting before-tax proceeds of $5-10 billion. Proceeds related to asset sales were $6.7 billion from January 2018 through September 2020.

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.

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Management’s commentary related to earnings trends for the company’s major business areas is as follows:

Upstream Earnings for the upstream segment are closely aligned with industry prices for crude oil and natural gas. Crude oil and natural gas prices are subject to external factors over which the company has no control, including product demand connected with global economic conditions, industry production and inventory levels, technology advancements, production quotas or other actions imposed by the Organization of Petroleum Exporting Countries (OPEC) or other producers, actions of regulators, weather-related damage and disruptions, competing fuel prices, natural and human causes beyond the company’s control such as the COVID-19 pandemic, 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 and other applicable laws and regulations.

The company is actively managing its schedule of work, contracting, procurement, and supply chain activities to effectively manage costs, ensure supply chain resiliency and continuity, and support operational goals. Third party costs for capital, exploration, and operating expenses associated with ongoing operations can be subject to external factors beyond the company’s control including, but not limited to: the general level of inflation, tariffs or other taxes imposed on goods or services, and market based prices charged by the industry’s material and service providers. Chevron utilizes contracts with various pricing mechanisms, so there may be a lag before the company’s costs reflect the changes in market trends.

The spot markets for many materials and services have fallen in response to the broader economic impact of the COVID-19 pandemic. While crude oil and natural gas prices have risen from the lows of the early pandemic, spending in the energy sector is limited. If future commodity prices remain below break-even levels, more highly-leveraged producers may be forced to file for bankruptcy protection (Chapter 11 re-organization or even Chapter 7 insolvency proceedings under the U.S. Bankruptcy Code), which could further stress suppliers. The extent to which the costs of goods and services could go down may be constrained by low supply sector margins, decisions by suppliers to reduce capacity, and actions by banks and other financial institutions. Chevron is actively monitoring and engaging key suppliers to mitigate any potential business impacts.

Capital and exploratory expenditures and operating expenses could also be affected by damage to production facilities caused by severe weather or civil unrest, delays in construction, or other factors.

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 $64 per barrel for the full-year 2019. During the third quarter 2020, Brent averaged $43 per barrel and ended October at about $36. The WTI price averaged $57 per barrel for the full-year 2019. During the third quarter 2020, WTI averaged $41 per barrel

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and ended October at about $36. The majority of the company’s equity crude production is priced based on the Brent benchmark. (See page 36 for the company’s average U.S. and international crude oil sales prices.)

Crude prices sharply declined at the end of the first quarter due to surplus supply as demand decreased due to government-imposed travel restrictions and other constraints on economic activity. In the second and third quarters the supply/demand balance improved primarily due to production cuts and demand growth, increasing prices.

In contrast to price movements in the global market for crude oil, price changes for natural gas are more closely aligned with seasonal supply-and-demand and infrastructure conditions in local markets. In the United States, prices at Henry Hub averaged $1.82 per thousand cubic feet (MCF) for the first nine months of 2020, compared with $2.59 during the first nine months of 2019. At the end of October 2020, the Henry Hub spot price was $3.00 per MCF.

Outside the United States, price changes for natural gas depend on a wide range of supply, demand and regulatory circumstances. Chevron sells natural gas into the domestic pipeline market in most locations. In some locations, Chevron has invested in long-term projects to produce and liquefy natural gas for transport by tanker to other markets. The company’s long-term contract prices for liquefied natural gas (LNG) are typically linked to crude oil prices. Most of the equity LNG offtake from the operated Australian LNG projects is committed under binding long-term contracts, with the remainder to be sold in the Asian spot LNG market. The Asian spot market reflects the supply and demand for LNG in the Pacific Basin and is not directly linked to crude oil prices. International natural gas sales realizations averaged $4.71 per MCF during the first nine months of 2020, compared with $5.87 per MCF in the same period last year. (See page 36 for the company’s average natural gas sales prices for the U.S. and international regions.)

The company’s worldwide net oil-equivalent production in the first nine months of 2020 averaged 3.018 million barrels per day, 1 percent lower than the year-ago period. About 14 percent of the company’s net oil-equivalent production in the first nine months of 2020 occurred in the OPEC-member countries of Angola, Nigeria, Republic of Congo and Venezuela. OPEC quotas did not materially reduce the company’s net crude oil production in third quarter 2020. OPEC quotas had no effect on the company’s net crude oil production for third quarter 2019.

The company expects 2020 production to be relatively flat compared to 2019. This estimate is subject to many factors and uncertainties, including quotas or other actions that may be imposed by OPEC members and other countries; price effects on entitlement volumes; changes in fiscal terms or restrictions on the scope of company operations; delays in construction; reservoir performance; greater-than-expected declines in production from mature fields; 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; storage constraints or economic conditions that could lead to shut-in production; or other disruptions to operations. The outlook for future production levels is also affected by the size and number of economic investment opportunities and the time lag between initial exploration and the beginning of production. The company has increased its investment emphasis on short-cycle projects, but these too are under pressure in the current market environment.

In the Partitioned Zone between Saudi Arabia and Kuwait, production was shut-in beginning in May 2015. In December 2019, the governments of Saudi Arabia and Kuwait signed a memorandum of understanding to allow production to restart in the Partitioned Zone. In mid-February 2020, pre-startup activities commenced, and production resumed in July 2020. The financial effects from the loss of production in 2019 and first half 2020 were not significant. During the third quarter 2020, oil equivalent production in the Partitioned Zone averaged 29 thousand barrels per day.

Chevron has interests in Venezuelan crude oil production assets, including those operated by independent equity affiliates. While the operating environment in Venezuela has been deteriorating for some time, the equity affiliates have conducted activities consistent with the authorization provided pursuant to general licenses issued by the United States government. During the second quarter 2020, the company completed its evaluation of the carrying value of its Venezuelan investments in line with its accounting policies and concluded that given the current operating environment and overall outlook, which created significant

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uncertainties regarding the recovery of the company’s investment, an other than temporary loss of value had occurred, which resulted in a full impairment of its investment in the country totaling $2.6 billion. As a result, the company also removed approximately 160 million barrels of proved reserves and stopped reporting production in the country effective July 2020. The company remains committed to its people, assets and operations in Venezuela.

Response to Market Conditions and COVID-19: Upstream In the third quarter 2020, travel restrictions and other constraints on economic activity aimed at combating the spread of COVID-19 continued, which caused demand for oil and gas to remain low. This has resulted in lower price realizations across all commodities. While critical asset integrity and reliability activities continue, deferral of non-essential work and demobilization of non-essential personnel have continued in locations with high infection rates to reduce the COVID-19 exposure risk to our workforce.

Despite the challenges posed by the pandemic, progress continues on the future growth wellhead pressure management project (FGP-WPMP) at Tengiz. To mitigate the risk from the pandemic, in the second quarter the project construction workforce was demobilized to 20 percent of planned levels, which slowed the overall construction pace. Extended rotations, testing and isolation protocols remain in place for personnel arriving and departing from the site to minimize the spread of the virus. Infection levels in Kazakhstan improved in the third quarter, allowing remobilization of the FGP-WPMP construction workforce to commence. Given the uncertainty of timing for safely completing remobilization and sustained activity levels, it is too early to provide meaningful information regarding impacts on project costs and schedule.

Facility maintenance turnarounds are being adjusted and, in certain cases, deferred to later in 2020 or into 2021. In some cases, turnarounds have been extended in duration and/or reduced in scope as a result of the virus. As a result of the reduction in capital expenditures, new production is expected to be significantly lower in future periods as drilling and completion activities are scaled back, most notably in the Permian Basin, Gulf of Mexico, and Argentina. Exploration activities and projects not yet in execution phase have been deferred, which may impact production in future years.

Production levels have been curtailed largely as a result of reductions imposed by OPEC+ nations in Kazakhstan, Nigeria and Angola. Additionally, although minor, reductions have been implemented by operators of assets where the company has non-operated interests or where production has been curtailed due to market conditions, most notably in Thailand. Production curtailments of approximately 154 thousand barrels of oil equivalent per day were recorded in the third quarter. In the fourth quarter, we expect curtailments to be approximately 100 thousand barrels of oil equivalent per day.

Decreased capital expenditures for 2020 will result in reductions to Chevron’s proved reserve quantities and delays in timing of additional proved reserves being recognized. The company currently estimates the lower planned capital spend will result in an approximately 10 percent downward revision to proved reserves quantities, primarily in the Permian Basin and Australia. As low commodity prices have persisted, it is expected that proved reserve quantities will decrease for oil and gas properties where economic limits are negatively impacted. Lower prices will positively impact proved reserves due to entitlement effects in production sharing contracts and variable royalty contracts. The impact of the reduction in capital expenditures, changes in commodity prices, and their combined effect on proved reserves will be assessed at the end of the year in line with Chevron’s annual reserves process.

Regulatory and in-country conditions, particularly as some countries face a resurgence of the virus, could impact logistics and material movement and remain a risk to business continuity. We are taking precautionary measures to reduce the risk of exposure to and spread of the COVID-19 virus through screening, testing and, when appropriate, quarantining workforce and visitors upon arrival to our operated facilities.

Refer to the “Results of Operations” section on pages 30 and 31 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

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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, and changes in tax laws and regulations.

The company’s most significant marketing areas are the West Coast and Gulf Coast of the United States and Asia. Chevron operates or has significant ownership interests in refineries in each of these areas.

Response to Market Conditions and COVID-19: Downstream Beginning in March and continuing into the fourth quarter 2020, demand for most of the company’s products (primarily jet fuel and motor gasoline) has been below prior year levels as a result of travel restrictions and other constraints on economic activity implemented in many countries to combat the spread of the COVID-19 virus. Product prices also fell sharply in the second quarter 2020, and although economic activity has somewhat rebounded from lows experienced in April, refining margins were at or near historic lows due to lower demand and pressure from a global oil product surplus for much of the third quarter. Chevron took steps to maximize diesel production, given the decline in jet fuel and motor gasoline demand, to fuel transportation that keeps global supply chains moving. The company is actively monitoring supply and demand dynamics as every region is experiencing different recovery trends. The company is adjusting the schedule for planned maintenance activity across its refining network and idling certain processing units to adjust for lower demand, reducing costs, managing inventories and, most importantly, protecting the safety of employees and contractors. To preserve cash and support balance sheet strength, the 2020 downstream organic capital spending program was reduced by approximately $800 million.

As of late October 2020, Chevron’s refining crude utilization was approximately 75 percent and sales were down year-over-year approximately 55 percent for jet fuel and less than 10 percent for motor gasoline, while diesel sales were relatively flat year-over-year. It is unclear how long these conditions will persist, but the company will continue to take actions necessary to protect the health and well-being of people, the environment and its operations as conditions evolve.

Refer to the “Results of Operations” section on pages 31 and 32 for additional discussion of the company’s downstream operations.

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

Operating Developments

Noteworthy operating developments in recent months included the following:

•United States - Chevron’s joint venture, CalBioGas LLC, successfully achieved first renewable natural gas production from dairy farms in California and marketed it as an alternative fuel for heavy-duty trucks and buses.

•United States - Announced an investment in Zap Energy Inc., a start-up company developing a next-generation modular nuclear reactor.

•United States - Completed the acquisition of Noble Energy, Inc. in October 2020.

•United States - Announced the formation in October 2020 of a joint venture with Brightmark LLC to produce and market dairy biomethane.

•United States - Signed an agreement in October 2020 to sell the Appalachia natural gas business.

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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 8, beginning on page 11, for a discussion of the company’s “reportable segments,” as defined under the accounting standards for segment reporting.)

Upstream

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
U.S. Upstream Earnings			$	116					$	727					$	(1,709)					$	2,371

U.S. upstream operations reported earnings of $116 million in third quarter 2020, compared with $727 million from a year earlier. The decrease was primarily due to lower crude oil realizations of $690 million.

U.S. upstream operations reported a loss of $1.71 billion for the first nine months of 2020, compared with earnings of $2.37 billion from a year earlier. The decrease is due to lower crude oil realizations of $2.76 billion and second quarter impairments of $1.13 billion.

The average realization per barrel for U.S. crude oil and natural gas liquids in third quarter 2020 was $31 compared with $47 a year earlier. The average realization per barrel for U.S. crude oil and natural gas liquids in the first nine months of 2020 was $30, compared with $49 a year earlier. The average natural gas realization in third quarter 2020 was $0.89 per thousand cubic feet, compared with $0.95 in the 2019 period. The average natural gas realization in the first nine months of 2020 was $0.77 per thousand cubic feet, compared with $1.09 in the 2019 period.

Net oil-equivalent production of 982,000 barrels per day in third quarter 2020 was up 48,000 barrels per day, or 5 percent, from a year earlier. Production increases from shale and tight properties in the Permian Basin in Texas and New Mexico were partially offset by normal field declines and planned maintenance in the Gulf of Mexico. Net oil-equivalent production of 1.01 million barrels per day in the first nine months of 2020 was up 106,000 barrels per day, or 12 percent, from a year earlier. Production increases from shale and tight properties in the Permian Basin in Texas and New Mexico were partially offset by normal field declines and the effects of production curtailments due to market conditions.

The net liquids component of oil-equivalent production of 731,000 barrels per day in third quarter 2020 was up 1 percent from the corresponding 2019 period. The net liquids component of oil-equivalent production of 760,000 barrels per day in the 2020 nine-month period was up 7 percent from the 2019 period. Net natural gas production was 1.51 billion cubic feet per day in third quarter 2020, an increase of 21 percent from the 2019 comparative period. Net natural gas production was 1.51 billion cubic feet per day in the first nine months of 2020, an increase of 28 percent from the 2019 period.

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
International Upstream Earnings*			$	119					$	1,977					$	(1,225)					$	6,939
_____________________________
*  Includes foreign currency effects			$	(107)					$	49					$	99					$	(97)

International upstream operations reported earnings of $119 million in third quarter 2020, compared with earnings of $1.98 billion a year ago. The decrease in earnings was primarily due to lower crude oil and natural gas realizations of $900 million and $410 million, respectively, lower crude oil and natural gas sales volumes of $400 million and $290 million, respectively, and a tax item related to an end-of-contract settlement of $130 million. Partially offsetting these items were lower depreciation and operating expenses of $250 million and $170 million, respectively. Foreign currency effects had an unfavorable impact on earnings of $156 million between periods.

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International upstream operations reported a loss of $1.23 billion in the first nine months of 2020 compared with earnings of $6.94 billion a year earlier. The decrease was primarily due to lower crude oil and natural gas realizations of $3.8 billion and $870 million, respectively, charges of $3.6 billion for impairments and write-offs, and lower crude oil and natural gas volumes of $760 million and $430 million, respectively. Partially offsetting these items were gains on asset sales of $550 million. Foreign currency effects had a favorable impact on earnings of $196 million between periods.

The average realization per barrel of crude oil and natural gas liquids in third quarter 2020 was $39, compared with $56 a year earlier. The average realization per barrel of crude oil and natural gas liquids in the first nine months of 2020 was $35, compared with $59 a year earlier. The average natural gas realization in third quarter 2020 was $3.89 per thousand cubic feet, compared with $5.62 in the 2019 period. The average natural gas realization in the first nine months of 2020 was $4.71 per thousand cubic feet, compared with $5.87 in the 2019 period.

International net oil-equivalent production of 1.85 million barrels per day in third quarter 2020 decreased 247,000 barrels per day, or 12 percent, from the corresponding 2019 period. The decrease is due to production curtailments associated with OPEC+ restrictions and market conditions combined with asset sale related decreases of 104,000 barrels per day. International net oil-equivalent production of 2.01 million barrels per day in the first nine months of 2020 was down 140,000 barrels per day, or 7 percent, from a year earlier. The decrease is due to asset sale related decreases of 100,000 barrels per day, and production curtailments associated with OPEC+ restrictions and market conditions, partially offset by higher production entitlement effects.

The net liquids component of oil-equivalent production of 976,000 barrels per day in third quarter 2020 decreased 12 percent from the 2019 period. The net liquids component of oil-equivalent production of 1.07 million barrels per day in the first nine months of 2020 decreased 7 percent from the 2019 period. Net natural gas production of 5.26 billion cubic feet per day in third quarter 2020 decreased 12 percent from the 2019 period. Net natural gas production of 5.61 billion cubic feet per day in the first nine months of 2020 decreased 6 percent from the 2019 period.

Downstream

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
U.S. Downstream Earnings			$	141					$	389					$	(397)					$	1,071

U.S. downstream operations reported earnings of $141 million in third quarter 2020, compared with $389 million a year earlier. The decrease was mainly due to lower sales volumes of $260 million and lower margins on refined product sales of $230 million, partially offset by lower operating expenses of $230 million.

U.S. downstream operations reported a loss of $397 million for the first nine months of 2020 compared with earnings of $1.07 billion a year earlier. The decrease was primarily due to lower sales volumes of $670 million, lower margins on refined product sales of $590 million and lower earnings from 50 percent-owned CPChem of $260 million.

Refinery crude oil input in third quarter 2020 decreased 17 percent to 820,000 barrels per day and for the first nine months of 2020, crude oil input decreased 16 percent to 789,000 barrels per day. The decrease for both comparative periods was due to the company's cut in refinery runs in response to lower demand from the impact of the COVID-19 pandemic and the weak refining margin environment.

Refined product sales of 1.00 million barrels per day were down 22 percent from third quarter 2019, mainly due to lower jet fuel, gasoline and diesel demand associated with the COVID-19 pandemic. Refined product sales of 997,000 barrels per day in the nine-month period were down 21 percent from the corresponding 2019 period, mainly due to lower jet fuel, gasoline and diesel demand associated with the COVID-19 pandemic.

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			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
International Downstream Earnings*			$	151					$	439					$	782					$	738
_______________________
*  Includes foreign currency effects			$	(49)					$	27					$	(12)					$	49

International downstream operations earned $151 million in third quarter 2020, compared with earnings of $439 million a year earlier. The decrease in earnings was largely due to lower margins on refined product sales of $270 million, partially offset by lower operating expenses of $50 million. Foreign currency effects had an unfavorable impact on earnings of $76 million between periods.

Earnings for the first nine months of 2020 were $782 million, compared with $738 million a year earlier. The increase in earnings was largely due to higher margins on refined product sales of $130 million, partially offset by lower asset sale gains of $30 million. Foreign currency effects had an unfavorable impact on earnings of $61 million between periods.

Refinery crude oil input of 570,000 barrels per day in third quarter 2020 decreased 9 percent from the year-ago period. For the first nine months of 2020, crude input was 598,000 barrels per day, down 5 percent from the year-ago period.

Total refined product sales of 1.28 million barrels per day in third quarter 2020 were down 6 percent from the year-ago period, mainly due to lower jet fuel demand associated with the COVID-19 pandemic, partially offset by higher diesel sales resulting from the second quarter 2020 acquisition of Puma Energy (Australia) Holdings Pty Ltd. Total refined product sales for the first nine months of 2020 of 1.22 million barrels per day were down 9 percent from the year-ago period, mainly due to lower jet fuel and gasoline demand associated with the COVID-19 pandemic.

All Other

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
Earnings/(Charges)*			$	(734)					$	(952)					$	(2,329)					$	(1,585)
______________________
*  Includes foreign currency effects			$	(32)					$	(2)					$	(198)					$	—

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

Net charges in third quarter 2020 were $734 million, compared to $952 million a year earlier. The decrease in net charges between periods was mainly due to the absence of a prior year tax charge. Higher corporate expenses partially offset the decrease between periods, primarily from a $90 million non-cash provision for remediation of a former mining asset. Foreign currency effects increased net charges by $30 million between periods.

Net charges for the first nine months of 2020 were $2.33 billion, compared with $1.59 billion a year earlier. The change between periods was mainly due to the absence of the Anadarko termination fee that was received in second quarter 2019 and second quarter 2020 severance charges, partially offset by the absence of a prior year tax charge. Foreign currency effects increased net charges by $198 million between periods.

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Consolidated Statement of Income

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

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
Sales and other operating revenues			$	23,997					$	34,779					$	69,628					$	105,291

Sales and other operating revenues decreased $10.8 billion for the quarterly period mainly due to lower refined product and crude oil prices and lower refined product volumes. Sales and other operating revenues for the nine-month period decreased $35.7 billion. The decrease was primarily due to lower crude oil and refined product prices, lower refined product volumes and lower natural gas prices.

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
Income from equity affiliates			$	510					$	1,172					$	(1,040)					$	3,430

Income from equity affiliates in the quarterly period decreased, mainly due to lower upstream-related earnings from Tengizchevroil in Kazakhstan and lower downstream-related earnings from GS Caltex in South Korea. Income from equity affiliates in the nine-month period decreased mainly due to the full impairment of Petropiar and Petroboscan in Venezuela and lower upstream-related earnings from Tengizchevroil in Kazakhstan.

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
Other income (loss)			$	(56)					$	165					$	858					$	1,445

Other income for the third quarter decreased due to an unfavorable swing in foreign currency effects. Other income for the nine-month period decreased due to the absence of the receipt of the second quarter 2019 Anadarko termination fee and an unfavorable swing in foreign currency effects, partially offset by gains on asset sales.

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
Purchased crude oil and products			$	13,448					$	19,882					$	37,101					$	60,420

Purchased crude oil and products for the third quarter decreased $6.4 billion, primarily due to lower crude oil and refined product prices. Purchased crude oil and products for the nine-month period decreased $23.3 billion, primarily due to lower crude oil and refined product prices and lower refined product and crude oil volumes.

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
Operating, selling, general and administrative expenses			$	5,436					$	6,279					$	18,509					$	18,412

Operating, selling, general and administrative expenses in the third quarter decreased $843 million, primarily due to lower maintenance expenses, lower employee expenses and lower expenses for non-operated upstream properties. The nine-month period increased $97 million, primarily due to severance accruals partially offset by lower non-severance related employee expenses, lower expenses for non-operated upstream properties and lower maintenance expense.

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			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
Exploration expenses			$	117					$	168					$	1,170					$	498

Exploration expenses in the third quarter decreased primarily due to lower geological and geophysical expenses. The increase in the nine-month period was mostly due to higher charges for well write-offs.

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
Depreciation, depletion and amortization			$	4,017					$	4,361					$	15,022					$	12,789

Depreciation, depletion and amortization expenses for the third quarter decreased primarily due to lower production. Depreciation, depletion and amortization expenses for the nine-month period increased mainly due to second quarter 2020 impairment charges.

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
Taxes other than on income			$	1,091					$	1,059					$	3,223					$	3,167

Taxes other than on income increased for the third quarter, mainly due to higher regulatory expenses and property taxes, partially offset by lower taxes on production. Taxes other than on income for the nine-month period increased mainly due to higher regulatory expenses and property taxes, partially offset by lower taxes on production, payroll and sales and use tax.

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
Interest and debt expense			$	164					$	197					$	498					$	620

Interest and debt expenses for the third quarter and the nine-month period decreased mainly due to lower interest rates.

			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
Income tax expense/(benefit)			$	165					$	1,469					$	(1,591)					$	4,429

The decrease in income tax expense for the third quarter 2020 of $1.30 billion was primarily due to the reduction in total income before tax for the company of $4.09 billion. The decrease in income before taxes was primarily due to lower prices and decreased production.

U.S. income before tax decreased from $728 million in third quarter 2019 to a loss of $662 million in 2020. This $1.39 billion decrease in income was primarily driven by lower prices, partially offset by increased production. The decrease in income had a direct impact on the company’s U.S. income tax resulting in a decrease to tax expense of $344 million between year-over-year periods, from a tax charge of $161 million in 2019 to a benefit of $183 million in 2020.

International income before tax decreased from $3.32 billion in third quarter 2019 to $618 million in 2020. This $2.70 billion decrease in income was primarily driven by lower prices and decreased production. The decrease in income and a lower one-time tax charge resulted in a $960 million decrease in international income tax expense between year-over-year periods, from $1.31 billion in 2019 to $348 million in 2020.

The company's decrease in income tax expense for the first nine months of 2020 of $6.02 billion was primarily due to the decrease in the total before-tax income in 2020 of $20.44 billion.

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U.S. income before tax decreased between the nine-month periods, from $3.08 billion in 2019 to a loss of $5.70 billion in 2020. This decrease in income was primarily driven by lower prices, the effects of impairments and other charges in the U.S., and the absence of the Anadarko merger termination fee, partially offset by an increase in production. The decrease in income had a direct impact on the company’s U.S. income tax resulting in a decrease in tax expense of $2.06 billion between the nine-month periods, from an expense of $801 million in 2019 to a benefit of $1.25 billion in 2020.

International income before tax decreased for the nine-month periods, from $10.86 billion in 2019 to a loss of $799 million in 2020. This decrease in income was primarily driven by lower prices and production volumes, the effects of impairments and other charges in international locations, partially offset by asset sales. The decrease in income before asset sale gains and the impact of tax benefits due to releasing the reserve on uncertain tax positions, valuation allowance releases, a rate change, and a lower one-time charge resulted in an overall decrease in international income tax expense of $3.97 billion between year-over-year periods, from a charge of $3.63 billion in 2019 to a benefit of $337 million in 2020.

Additional information related to the company’s effective income tax rate is included in Note 11 to the Consolidated Financial Statements.

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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 September 30												Nine Months Ended September 30
			2020						2019						2020						2019
U.S. Upstream
Net crude oil and natural gas liquids production (MBPD)			731						726						760						709
Net natural gas production (MMCFPD)(3)			1,507						1,243						1,511						1,178
Net oil-equivalent production (MBOEPD)			982						934						1,012						906
Sales of natural gas (MMCFPD)			3,776						3,945						4,000						3,980
Sales of natural gas liquids (MBPD)			205						128						203						118
Revenue from net production
Liquids ($/Bbl)			$	31.33					$	46.84					$	29.53					$	49.22
Natural gas ($/MCF)			$	0.89					$	0.95					$	0.77					$	1.09
International Upstream
Net crude oil and natural gas liquids production (MBPD)(4)			976						1,104						1,072						1,147
Net natural gas production (MMCFPD)(3)			5,257						5,972						5,609						5,995
Net oil-equivalent production (MBOEPD)(4)			1,852						2,099						2,006						2,146
Sales of natural gas (MMCFPD)			5,513						5,923						5,722						5,922
Sales of natural gas liquids (MBPD)			53						31						47						36
Revenue from liftings
Liquids ($/Bbl)			$	38.96					$	56.07					$	34.70					$	58.67
Natural gas ($/MCF)			$	3.89					$	5.62					$	4.71					$	5.87
U.S. and International Upstream
Total net oil-equivalent production (MBOEPD)(4)			2,834						3,033						3,018						3,052
U.S. Downstream
Gasoline sales (MBPD)(5)			603						702						577						670
Other refined product sales (MBPD)			401						592						420						585
Total refined product sales (MBPD)			1,004						1,294						997						1,255
Sales of natural gas liquids (MBPD)			25						105						25						95
Refinery input (MBPD)			820						992						789						939
International Downstream
Gasoline sales (MBPD)(5)			242						256						227						264
Other refined product sales (MBPD)			690						701						640						703
Share of affiliate sales (MBPD)			350						399						352						377
Total refined product sales (MBPD)			1,282						1,356						1,219						1,344
Sales of natural gas liquids (MBPD)			80						71						79						75
Refinery input (MBPD)			570						625						598						630
________________________________
(1)  Includes company share of equity affiliates.
(2)  MBPD — thousands of barrels per day; MMCFPD — millions of cubic feet per day; Bbl — Barrel; MCF — thousands of cubic feet; oil-equivalent gas conversion ratio is 6,000 cubic feet of natural gas = 1 barrel of crude oil; MBOEPD — thousands of barrels of oil-equivalent per day.
(3)  Includes natural gas consumed in operations (MMCFPD):
United States			35						34						34						34
International			535						611						571						611
(4)  Includes net production of synthetic oil:
Canada			35						53						52						51
Venezuela affiliate			—						—						—						4
(5)  Includes branded and unbranded gasoline.

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Liquidity and Capital Resources

Cash, cash equivalents and marketable securities totaled $6.9 billion at September 30, 2020 and $5.7 billion at year-end 2019. Cash provided by operating activities in the first nine months of 2020 was $8.3 billion, compared with $21.7 billion in the year-ago period. Cash capital and exploratory expenditures totaled $7.3 billion in the first nine months of 2020, down $3.1 billion from the year-ago period. Proceeds and deposits related to asset sales and returns of investment totaled $1.9 billion and $67 million, respectively, in the first nine months of 2020, compared to $1.0 billion and $67 million, respectively, in the year-ago period.

Dividends The company paid dividends of $7.2 billion to common stockholders during the first nine months of 2020. In October 2020, the company declared a quarterly dividend of $1.29 per common share, payable in December 2020.

Debt and Finance Lease Liabilities Chevron’s total debt and finance lease liabilities were $34.8 billion at September 30, 2020, up from $27.0 billion at December 31, 2019, following the company’s issuance of long-term public bonds of $8.0 billion in May 2020 and $4.0 billion in August 2020, partially offset by repayment of long-term notes that matured during the first nine months of 2020. More information on bond issuances is included in Note 19 on page 22.

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 September 30, 2020 was $4.3 billion. The company’s debt and finance lease liabilities due within one year, consisting primarily of commercial paper, redeemable long-term obligations and the current portion of long-term debt, totaled $10.3 billion at September 30, 2020, and $13.0 billion at December 31, 2019. Of these amounts, $9.75 billion was reclassified to long-term at both September 30, 2020, and December 31, 2019. At September 30, 2020, settlement of these obligations was not expected to require the use of working capital within one year, as the company had the intent and the ability, as evidenced by committed credit facilities, to refinance them on a long-term basis.

At September 30, 2020, the company had $9.75 billion in 364-day committed credit facilities with various major banks that enable the refinancing of short-term obligations on a long-term basis. The credit facilities allow the company to convert any amounts outstanding into a term loan for a period of up to one year. 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 September 30, 2020. In addition, the company has an automatic shelf registration statement that expires in August 2023 for an unspecified amount of nonconvertible debt securities issued by Chevron Corporation or Chevron U.S.A. Inc. (CUSA).

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, CUSA 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 (S&P) and Aa2 by Moody’s Investors Service (Moody’s). The company’s U.S. commercial paper is rated A-1+ by S&P and P-1 by Moody’s. All of these ratings denote high-quality, investment-grade securities. As a result of deteriorating market conditions for the energy industry, S&P and Moody’s conducted credit reviews and reaffirmed the company’s debt ratings in March and April 2020, respectively. In July 2020, following the announcement by the company of the proposed acquisition of Noble Energy, and in September 2020 upon completion of its annual review, S&P reaffirmed the rating.

The company’s future debt level is dependent primarily on results of operations, cash that may be generated from asset dispositions, the capital program, lending commitments to affiliates, and shareholder distributions. 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 has the flexibility to modify capital spending plans, discontinue or curtail the stock repurchase program (which is currently suspended),

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sell assets, and increase borrowings to continue paying the common stock dividend. The company remains committed to retaining its high-quality debt ratings.

Summarized Financial Information for Guarantee of Securities of Subsidiaries In August 2020, long-term public bonds referred to in Note 19 on page 22 were issued by CUSA and fully and unconditionally guaranteed on an unsecured basis by Chevron Corporation (together the “Obligor Group”). In March 2020, the U.S. Securities and Exchange Commission (SEC) issued a final rule that amended the disclosure requirements with respect to certain guaranteed securities registered or being registered in Rule 3-10 of Regulation S-X and adopted new Rule 13-01 of Regulation S-X. These amendments are effective January 4, 2021, with early adoption permitted. Chevron Corporation has elected to early adopt the final rule beginning July 1, 2020. Accordingly, as disclosed in the tables below, summary financial information is presented for Chevron Corporation, as Guarantor, excluding its consolidated subsidiaries, and CUSA, as the issuer, excluding its consolidated subsidiaries. The summary financial information of the Obligor Group is presented on a combined basis and transactions between the combined entities have been eliminated. Financial information for non-guarantor entities has been excluded.

			Nine Months Ended September 30, 2020						Year Ended December 31, 2019
			(Millions of dollars) (unaudited)
Sales and other operating revenues			$	37,201					$	82,206
Sales and other operating revenues - related party			12,672						24,336
Total costs and other deductions			42,694						87,287
Total costs and other deductions - related party			10,467						22,632
Net income (loss)			$	(746)					$	2,173

			At September 30, 2020						At December 31, 2019
			(Millions of dollars) (unaudited)
Current assets			$	8,763					$	10,180
Current assets - related party			5,016						952
Other assets			49,603						50,595
Current liabilities			19,847						25,187
Current liabilities - related party			53,101						46,237
Other liabilities			33,667						25,622
Total net equity (deficit)			$	(43,233)					$	(35,319)

Common Stock Repurchase Program On February 1, 2019, the company announced that the Board of Directors authorized a new stock repurchase program with a maximum dollar limit of $25 billion and no set term limits. As of September 30, 2020, the company had purchased 48.6 million shares for $5.5 billion, resulting in $19.5 billion remaining under the authorized program. On March 24, 2020, the company announced the suspension of the stock repurchase program in response to market conditions. No shares were purchased under the program in third quarter 2020.

Repurchases may be made from time to time in the open market, by block purchases, in privately negotiated transactions or in such other manner as determined by the company. The timing of the repurchases and the actual amount repurchased will depend on a variety of factors, including the market price of the company’s shares, general market and economic conditions, and other factors. The stock repurchase program does not obligate the company to acquire any particular amount of common stock, and it may be discontinued or resumed at any time.

Noncontrolling Interests The company had noncontrolling interests of $264 million at September 30, 2020, and $1.0 billion at December 31, 2019. The decrease was primarily due to the acquisition in second quarter 2020 of an equity interest that was previously held by a joint venture partner. There were distributions of $10 million to noncontrolling interests during the first nine months of 2020 compared to $16 million for the same period in 2019.

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Financial Ratios and Metrics

			At September 30, 2020												At December 31, 2019
Current Ratio *			1.3												1.1
Debt Ratio			20.9			%									15.8			%
Net Debt Ratio			17.5			%									12.8			%

* At September 30, 2020, the book value of inventory was lower than replacement cost.

									Nine Months Ended September 30
															2020						2019
									(Millions of dollars)
Net cash provided by operating activities															$	8,339					$	21,657
Less: Capital expenditures															(6,855)						(9,906)
Free Cash Flow															$	1,484					$	11,751

Pension Obligations Information related to pension plan contributions is included on page 13 in Note 9 to the Consolidated Financial Statements.

Capital and Exploratory Expenditures Total expenditures, including the company’s share of spending by affiliates, were $10.3 billion in the first nine months of 2020, compared with $15.0 billion in the corresponding 2019 period. The amounts included the company’s share of affiliates’ expenditures of $3.1 billion and $4.6 billion in the 2020 and 2019 periods, respectively, which did not require cash outlays by the company. Expenditures for upstream projects in the first nine months of 2020 were $8.4 billion, representing 82 percent of the company wide total. Included in the 2020 period were inorganic capital expenditures of $350 million, primarily associated with the downstream acquisition of Puma Energy (Australia) Holdings Pty Ltd.

The decrease is consistent with the May 1, 2020 revision to organic capital expenditure guidance for 2020 to be as low as $14 billion. The incremental reductions are primarily focused on TCO’s major capital project, deferral of short-cycle investments and pacing projects not yet under construction in response to market conditions. The company is focused on completing projects already under construction that will start-up in future years while preserving the capability to increase short-cycle activity in the Permian Basin and other areas when commodity prices recover.

Capital and Exploratory Expenditures by Major Operating Area
			Three Months Ended September 30												Nine Months Ended September 30
			2020						2019						2020						2019
			(Millions of dollars)
United States
Upstream			$	904					$	2,102					$	3,932					$	5,929
Downstream			296						327						750						1,381
All Other			44						102						183						233
Total United States			1,244						2,531						4,865						7,543
International
Upstream			1,119						2,137						4,499						6,873
Downstream			228						284						949						550
All Other			1						4						9						12
Total International			1,348						2,425						5,457						7,435
Worldwide			$	2,592					$	4,956					$	10,322					$	14,978

Contingencies and Significant Litigation

MTBE Information related to methyl tertiary butyl ether (MTBE) matters is included on page 15 in Note 12 to the Consolidated Financial Statements under the heading “MTBE.”

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Ecuador Information related to Ecuador matters is included beginning on page 15 in Note 12 to the Consolidated Financial Statements under the heading “Ecuador.”

Income Taxes Information related to income tax contingencies is included beginning on page 14 in Note 11 and page 16 in Note 13 to the Consolidated Financial Statements under the heading “Income Taxes.”

Guarantees Information related to the company’s guarantees is included on page 17 in Note 13 to the Consolidated Financial Statements under the heading “Guarantees.”

Indemnifications Information related to indemnifications is included on page 17 in Note 13 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 17 in Note 13 to the Consolidated Financial Statements under the heading “Off-Balance-Sheet Obligations.”

Environmental Information related to environmental matters is included on page 17 in Note 13 to the Consolidated Financial Statements under the heading “Environmental.”

Other Contingencies Information related to the company’s other contingencies is included on pages 17 and 18 in Note 13 to the Consolidated Financial Statements under the heading “Other Contingencies.”

Item 3.Quantitative and Qualitative Disclosures About Market Risk

Information about market risks for the nine months ended September 30, 2020, does not differ materially from that discussed under Item 7A of Chevron’s 2019 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 Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended) as of the end of the period covered by this report. Based on this evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the company’s disclosure controls and procedures were effective as of September 30, 2020.

(b) Changes in internal control over financial reporting

During the quarter ended September 30, 2020, 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.

PART II

OTHER INFORMATION

Item 1.Legal Proceedings

Governmental Proceedings The following is a description of legal proceedings that the company has determined to disclose for this reporting period that involve governmental authorities and certain monetary sanctions under federal, state and local laws that have been enacted or adopted regulating the discharge of materials into the environment or primarily for the purpose of protecting the environment. The following proceedings include those matters relating to third quarter 2020 and any material developments with respect to matters previously reported in Chevron’s 2019 Annual Report on Form 10-K. 

As previously disclosed, the California Department of Conservation, Geologic Energy Management Division (CalGEM) (previously known as the Division of Oil, Gas and Geothermal Resources) promulgated revised rules pursuant to the Underground Injection Control program that took effect April 1, 2019. Subsequent to that date, CalGEM issued Notices of Violation (NOVs) and two orders to Chevron related to seeps that occurred in the Cymric Oil Field in Kern County, California. An October 2, 2019 CalGEM order (Order) seeks a civil penalty of approximately $2.7 million. Chevron has filed an appeal of the Order. Chevron is currently in discussions with CalGEM to explore a global settlement to resolve the Order and all past and

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present seeps in the Cymric Field, which would increase the amount of the penalty paid. Other state agencies may become engaged in settlement discussions with Chevron as well relating to this matter. Resolution of this matter may result in the payment of civil penalties of $100,000 or more.

On August 6, 2020, Chevron received a proposal from California’s Bay Area Air Quality Management District seeking to resolve certain NOVs related to alleged violations that occurred at Chevron's Richmond Refinery between 2017 and 2019. Resolution of the alleged violations 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 12 to the Consolidated Financial Statements.

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 nine months ended September 30, 2020, does not differ materially from that set forth under the heading “Risk Factors” on pages 18 through 21 of the company’s 2019 Annual Report on Form 10-K, other than as reflected in the risk factors below.

Impacts of the coronavirus disease 2019 (COVID-19) pandemic and geopolitical factors have resulted in a significant decrease in demand for Chevron’s products and caused a precipitous drop in commodity prices, which has had and is expected to continue to have an adverse, and potentially material adverse, effect on Chevron’s future financial and operating results.

As of the date of this Quarterly Report on Form 10-Q, the economic, business, and oil and gas industry impacts from the COVID-19 pandemic and the disruption to capital markets have continued to be far reaching. Crude oil prices, the single largest variable that affects the company’s results of operations, have fallen dramatically to historic lows, even briefly going negative, due to a combination of a severely reduced demand for crude oil, gasoline, jet fuel, diesel fuel, and other refined products resulting from government-mandated travel restrictions and the curtailment of economic activity resulting from the COVID-19 pandemic. As a result, a market imbalance has existed and may continue to exist, with oil supplies vastly exceeding current and expected near-term demand. Although OPEC and other countries have agreed to cut global oil supply, the commitments and actions to date have not matched the dramatic decrease in global demand, which has resulted in increased inventory levels in refineries, pipelines and storage facilities in prior periods and which may drive increased inventory levels in future periods.

Extended periods of low prices for crude oil are expected to have a material adverse effect on the company’s results of operations, financial condition and liquidity. Among other things, the company’s earnings, cash flows, and capital and exploratory expenditure programs are expected to be negatively affected, as are its production volumes and proved reserves. As a result, the value of the company’s assets may also become impaired in future periods, as we saw in the second quarter 2020.

The company’s operations and workforce are being impacted by the COVID-19 pandemic, causing certain operations to be curtailed to various degrees, which may become suspended completely if adverse conditions deteriorate further. At 50 percent-owned Tengizchevroil in Kazakhstan, COVID-19 infections have led to the demobilization of a significant portion of the workforce, adversely impacting the construction pace for completion of the FGP-WPMP project. Although infection levels in Kazakhstan improved in the third quarter 2020, allowing remobilization of the FGP-WPMP construction workforce to commence, the ultimate effects of COVID-19 on FGP-WPMP construction remain uncertain and cannot be predicted at this time. In particular, we are currently unable to predict whether COVID-19 will have a material adverse impact on our ability to complete FGP-WPMP on schedule or within the current cost estimate for the project.

As a result of decreased demand for its products, the company has made cuts to its upstream capital and exploratory expenditure program for 2020, which are expected to negatively impact future production, have led to and could lead to further negative revisions of reserves and could also lead to the further impairment of assets. Production curtailments, such as those due to the reductions imposed by OPEC+ nations in

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Kazakhstan, Nigeria and Angola, and other production curtailment actions taken by operators of assets for which the company has non-operated interests or due to market conditions, have exacerbated and are expected to continue to further exacerbate these negative impacts in future periods. Within downstream, the company reduced its capital spending program and is also deferring certain discretionary maintenance activities while maintaining expenditures for asset integrity and reliability. The company has reduced the utilization rates of its refineries in response to reduced demand for its products, particularly greatly reduced demand for jet fuel due to the COVID-19 impact on travel and the aviation industry, for which we are a key supplier, and these actions are expected to negatively impact future earnings and cash flows.

The company’s suppliers are also being impacted by the COVID-19 pandemic and access to materials, supplies, and contract labor has been strained. In certain cases, the company has received notices invoking force majeure provisions in supplier contracts. This strain on the financial health of the company’s suppliers could put further pressure on the company’s financial results and may negatively impact supply assurance and supplier performance. In-country conditions, including potential future waves of the COVID-19 virus in countries that appear to have reduced their infection rates, could impact logistics and material movement and remain a risk to business continuity.

In light of the significant uncertainty around the duration and extent of the impact of the COVID-19 pandemic, management is currently unable to develop with any level of confidence estimates and assumptions that may have a material impact on the company’s consolidated financial statements and financial or operational performance in any given period. In addition, the unprecedented nature of such market conditions could cause current management estimates and assumptions to be challenged in hindsight.

There continues to be uncertainty and unpredictability about the impact of the COVID-19 pandemic on our financial and operating results in future periods. The extent to which the COVID-19 pandemic adversely impacts our future financial and operating results, and for what duration and magnitude, depends on several factors that are continuing to evolve, are difficult to predict and, in many instances, are beyond the company's control. Such factors include the duration and scope of the pandemic, including any resurgences of the pandemic, and the impact on our workforce and operations; the negative impact of the pandemic on the economy and economic activity, including travel restrictions and prolonged low demand for our products; the ability of our affiliates, suppliers and partners to successfully navigate the impacts of the pandemic; the actions taken by governments, businesses and individuals in response to the pandemic; the actions of OPEC and other countries that otherwise impact supply and demand and correspondingly, commodity prices; the extent and duration of recovery of economies and demand for our products after the pandemic subsides; and Chevron’s ability to keep its cost model in line with changing demand for our products.

The impact of the COVID-19 pandemic is rapidly evolving, and the continuation or a resurgence of the pandemic could precipitate or aggravate the other risk factors identified in our 2019 Form 10-K, which in turn could further materially and adversely affect our business, financial condition, liquidity, results of operations and profitability, including in ways not currently known or considered by us to present significant risks.

The Noble Energy acquisition may cause our financial results to differ from our expectations or the expectations of the investment community, we may not achieve the anticipated benefits of the acquisition, and the acquisition may disrupt our current plans or operations.

The success of the Noble Energy acquisition, which closed in October 2020, will depend, in part, on Chevron’s ability to successfully integrate the business of Noble Energy and realize the anticipated benefits, including the anticipated annual run-rate operating and other cost synergies and accretion to return on capital employed, free cash flow and earnings per share. Difficulties in integrating Noble Energy may result in the failure to realize anticipated synergies in the expected timeframe, in operational challenges, and in the diversion of management’s attention from ongoing business concerns as well as in unforeseen expenses associated with the acquisition, which may have an adverse impact on our financial results.

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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						Approximate Dollar Value of Shares that May Yet Be Purchased Under the Program (2) (Billions of dollars)
July 1 – July 31, 2020			2,220						$	87.58					—						$19.5
August 1 – August 31, 2020			—						—						—						$19.5
September 1 – September 30, 2020			—						—						—						$19.5
Total			2,220						$	87.58					—

______________________________________

(1)Includes common shares repurchased from participants in the company’s deferred compensation plans for personal income tax withholdings.

(2)Refer to “Liquidity and Capital Resources” on pages 37 to 39 for additional information regarding the company’s authorized stock repurchase program. The stock repurchase program was suspended in March 2020.

Item 5.Other Information

Rule 10b5-1 Plan Elections

Pierre R. Breber, Vice President and Chief Financial Officer, entered into a pre-arranged stock trading plan in August 2020. Mr. Breber’s plan provides for the potential exercise of vested stock options and the associated sale of up to 13,000 shares of Chevron common stock between November 2020 and January 2021.

Rhonda J. Morris, Vice President and Chief Human Resources Officer, and her spouse entered into pre-arranged stock trading plans in August 2020. The plans for Ms. Morris and her spouse provide for the potential exercise of vested stock options and the associated sale of up to 7,200 and 7,500 shares of Chevron common stock, respectively, between November 2020 and January 2021.

These trading plans were entered into during an open insider trading window and are intended to satisfy Rule 10b5-1(c) under 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
3.1						By-Laws of Chevron Corporation, as amended and restated on September 30, 2020, filed as Exhibit 3.1 to Chevron Corporation's Current Report on Form 8-K filed October 2, 2020, and incorporated herein by reference.
4.1						Indenture, dated as of August 12, 2020, among Chevron U.S.A. Inc., Chevron Corporation, as guarantor, and Deutsche Bank Trust Company Americas, as trustee, filed as Exhibit 4.1 to Chevron Corporation's Current Report on Form 8-K filed August 13, 2020, and incorporated herein by reference.
4.2						First Supplemental Indenture, dated as of August 12, 2020, among Chevron U.S.A. Inc., Chevron Corporation, as guarantor, and Deutsche Bank Trust Company Americas, as trustee, filed as Exhibit 4.2 to Chevron Corporation's Current Report on Form 8-K filed August 13, 2020, and incorporated herein by reference.
4.3						Forms of 0.333% Notes Due 2022, Floating Rate Notes Due 2022, 0.426% Notes Due 2023, Floating Rate Notes Due 2023, 0.687% Notes Due 2025, 1.018% Notes Due 2027 and 2.343% Notes Due 2050, contained in Exhibit 4.2 to Chevron Corporation's Current Report on Form 8-K filed August 13, 2020, and incorporated herein by reference.
22.1*						Subsidiary Issuer of Guaranteed Securities
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.SCH*						iXBRL Schema Document
101.CAL*						iXBRL Calculation Linkbase Document
101.DEF*						iXBRL Definition Linkbase Document
101.LAB*						iXBRL Label Linkbase Document
101.PRE*						iXBRL Presentation Linkbase Document
104*						Cover Page Interactive Data File (contained in Exhibit 101)

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

______________________________

*    Filed herewith.

** Furnished herewith

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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/    DAVID A. INCHAUSTI
			David A. Inchausti, Vice President and Controller (Principal Accounting Officer and Duly Authorized Officer)

Date: November 5, 2020

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